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MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, January 2, 2026 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 11-07 PRUDHOE BAY UNIT 11-07 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/02/2026 11-07 50-029-20687-00-00 181-177-0 W SPT 8137 1811770 2100 1852 1854 1850 1839 116 324 316 309 REQVAR P Guy Cook 11/9/2025 2 year MIT-IA to greater of 0.25 x packer TVD or max injection pressure per AA AIO 4G.009. PWI maximum header pressure is 2100 psi. Testing was completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT 11-07 Inspection Date: Tubing OA Packer Depth 673 2662 2604 2590IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC251109155029 BBL Pumped:1.5 BBL Returned:1.5 Friday, January 2, 2026 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, January 12, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 11-07 PRUDHOE BAY UNIT 11-07 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/12/2024 11-07 50-029-20687-00-00 181-177-0 W SPT 8137 1811770 2150 1869 1868 1863 1863 145 356 340 335 REQVAR P Sully Sullivan 11/6/2023 2 year mitia per AIO 4g.009 (max hdr pressure) tested with 130deg diesel. Operater tested to 2645 for 500 psi diff 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT 11-07 Inspection Date: Tubing OA Packer Depth 631 2645 2583 2575IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS231108125733 BBL Pumped:1.6 BBL Returned:1.6 Friday, January 12, 2024 Page 1 of 1 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 11-07 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 181-177 50-029-20687-00-00 9472 Conductor Surface Intermediate Tie Back Liner Liner 8986 80 2627 8257 8039 1380 9137 20" 13-3/8" 9-5/8" 7" 7" 8669 32 - 112 32 - 2659 50 - 8287 30 - 8070 8092 - 9472 32 - 112 32 - 2659 40 - 7861 30 - 7659 7680 - 8986 9270 470 2670 4760 5410 5410 9137 1490 5380 6870 7240 7240 8951 - 9312 4-1/2" 12.6# L-80 28 - 8674 8493 - 8835 Structural 7" HES TNT , 7972 , 7569 No SSSV 7972 , 8415 , 8586 7569 , 7982 , 8146 Bo York Operations Manager David Wages David.Wages@hilcorp.com (713) 380-9836 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028325 28 - 8229 0 0 0 0 19760 22620 930 900 1983 1942 N/A 13b. Pools active after work:PRUDHOE OIL 4-1/2" HES TNT, 8415 , 7982 4-1/2" Baker S-3 , 8586 , 8146 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.01.09 15:52:53 - 09'00' Bo York (1248) By Grace Christianson at 2:03 pm, Jan 10, 2024 WCB 2024-06-24 DSR-1/26/24 ACTIVITYDATE SUMMARY 12/7/2023 *** WELL FLOWING ON ARRIVAL *** DRIFT TBG W/ 30' X 3.66 DMY GUN TAG HEX PLUG @ 9103' SLM ** WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED *** 12/14/2023 ***WELL INJECTING ON ARRIVAL*** PT PCE 250LP-3000HP LOG CORRELATED TO HES JEWELRY LOG DATED 8-SEP-2019 PERFORATE WITH 3-1/8" X 31' GEO BASIX GUN, 22.7 GRAM CHARGES, 60 DEG PHASED, 6 SPF, FROM 8951' - 8982' MD. GOOD INDICATION OF SHOOTING....POOH. CCL STOP DEPTH=8942.6' MD, CCL TO TS=8.4'. ***WELL INJECTING ON DEPARTURE*** Daily Report of Well Operations PBU 11-07 Adperfs are correctly shown on the new WBS, below. -WCB PERFORATE WITH 3-1/8" X 31' GEO BASIX GUN, 22.7 GRAM CHARGES, 60 DEG PHASED, 6 SPF, FROM 8951' - 8982' MD. GOOD INDICATION OF SHOOTING....POOH. 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 11-07 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 181-177 50-029-20687-00-00 9472 Conductor Surface Intermediate Tie Back Liner Liner 8986 80 2627 8257 8039 1380 9137 20" 13-3/8" 9-5/8" 7" 7" 8669 32 - 112 32 - 2659 50 - 8287 30 - 8070 8092 - 9472 32 - 112 32 - 2659 40 - 7861 30 - 7659 7680 - 8986 9270 470 2670 4760 5410 5410 9137 1490 5380 6870 7240 7240 8987 - 9312 4-1/2" 12.6# L-80 28 - 8674 8527 - 8835 Structural 7" HES TNT , 7972 , 7569 No SSSV 7972 , 8415 , 8586 7569 , 7982 , 8146 Bo York Operations Manager David Wages David.Wages@hilcorp.com (713) 380-9836 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028325 28 - 8229 0 0 0 0 6980 12053 0 0 1858 1741 N/A 13b. Pools active after work:PRUDHOE OIL 4-1/2" HES TNT, 8415 , 7982 4-1/2" Baker S-3 , 8586 , 8146 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 8:16 am, Aug 01, 2023 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2023.07.31 12:27:25 -08'00' DSR-8/4/23 RBDMS JSB 080323 WCB 3-8-2024 ACTIVITYDATE SUMMARY 6/10/2023 T/I/O=1226/1222/117 (SCHMOO-B-GONE) Pumped 3 bbls 60/40 down TBG. Pumped 150 bbls SBG down TBG. Pumped 3 bbls 60/40 Down TBG. Soak for 3 hours. ***Job Continued 6/11/23*** 6/11/2023 *** Job Continued 6/10/23 *** (SCHMOO-B-GONE) Pumped 115 bbls 1%kcl down TBG. Pumped 3 bbls 60/40 down TBG. Soak time finished at 4:30 am FWHP=1605/523/0 Turn well over to dso. SV,WV=Closed SSV,MV,IA,OA=Open upon departure. 6/17/2023 T/I/O=300/440/0 Assist S-Line (PERFORATING) Freeze Protect TBG w/ 40 bbls Crude FWHP= 1100/440/0 6/17/2023 ***WELL INJECTING ON ARRIVAL*** RAN 6' x 3.66" x 21' x 3.16" DUMMY GUNS, SD @1,430' SLM, UNABLE TO WORK DEEPER *****FISH IN HOLE, TOOLSTRING & TOOLS LIH (=50')**** *****10' x 1-3/4" STEM, OJ,KJ-LSS, 6' x 3.66" x 21' x 3.16" DUMMY GUNS***** ***WELL S/I ON DEPARTURE*** 6/23/2023 T/I/O= 186/-15/-10 (PERFORATING) Assist SL with Brush & Flush / Fishing - Pumped 106 bbls of 190* rude to assist SL. SL in control of well upon departure. FWHPs= 1056/-14/-7 6/23/2023 ***WELL S/I ON ARRIVAL*** (Perforating) RAN 3.25" LIB, UNABLE TO PASS 5,179' SLM BRUSH & FLUSHED TBG DWN TO FISH @ 9217' SLM w/ FULL BORE BRUSH, 3.60" BELL GUIDE & 2-1/2" SPLIT SKIRT JUS LRS PUMPED 106 BBLS CRUDE FOR BRUSH & FLUSH RECOVERED FISH @ 9217' SLM (all parts of TS accounted for) DRIFT TBG w/ 2.5" SAMPLE BAILER TO TAG @ 9276' SLM (bailer full of dry schmoo) RAN RCH 40 ARM CALIPER FROM 9,270' SLM TO SURFACE (good data) ***CONTINUE ON 6/24/23 WSR*** 6/24/2023 ***CONTINUED FROM 6/23/23 WSR*** (Perforating) POLLARD #60 RIG DOWN ***WELL S/I ON DEPARTURE*** 6/27/2023 (TFS Unit 4 Assist E-Line with Perforating) Job Postponed, no fluids pumped. 6/28/2023 T/I/O= 571/0/0 Temp=S/I (TFS Unit 4 Assist E-Line) Pumped 2 bbls of 50/50 followed by 282 bbls of 1% KCL down TBG. Pumped 150 bbls of Borax down TBG followed by 201 bbls of 1% KCL. Further pumped 38 bbls of Crude down TBG for Freeze Protect. Tags hung and Pad Op notified Well left in E-Line control Final WHPS 1165/0/0 Daily Report of Well Operations PBU 11-07 Daily Report of Well Operations PBU 11-07 6/28/2023 CONTACT DSO - PERMIT RIG UP PT LUBRICATOR TO LOW- 300 _ HIGH- 3000 AGAINST SWAB VALVE OPEN WELL RIH TO 9284 FT. CORRELATED DEPTH TO HES JEWELRY LOG DATED 8-SEPT- 2019 LOAD WELL WITH 230 BBLS OF 1% KCL FLUID LOG RMT-3D PRESSURE TEMP SIGMA BASELINE AND REPEAT PASS FROM 9284' - 8940' PER PROCEDURE LOAD WELL WITH 150 BBLS OF BORAX FLUID PLUS 35 BBLS OF 1% KCL FLUID LOG RMT-3D PRESSURE TEMP BORAX X 2 PASSES FROM 9284' - 8940' PER PROCEDURE LOAD WELL WITH 100 BBLS OF 1% KCL FLUID LOG RMT-3D PRESSURE TEMP FLUSH X 1 PASS FROM 9284' - 8940' PER PROCEDURE TO ENSURE BORAX REMOVED FROM WELLBORE. LOGGING COMPLETE POOH WITH TOOLSTRING - CLOSE SWAB- BLEED OFF PRESSURE LAY DOWN EQUIPMENT FOR THE NIGHT SECURE WELL CONTACT DSO AND LEAVE LOCATION 6/29/2023 ARRIVE LOCATION - CONTACT DSO - PERMIT PRE-JOB JSA P/U LUB WITH GUN #1 P/T LOW-300PSI, HIGH-3000PSI RIH W/ GUN #1 - 2.875" HSC MAXFORCE GUN , 6 SPF, 60 DEG PHASED AND PERFORATE 8987' - 9018.5' PER HES JEWELRY LOG DATED 08-SEPT-2019. REFERENCE LOG DEPTH = 8987' - 9018.5'. CCL OFFSET = 8 FT. CCL STOP DEPTH = 8979 FT. POOH AND CONFIRM ALL SHOTS FIRED RIH W/ GUN #2 - 2.875" HSC MAXFORCE GUN , 6 SPF, 60 DEG PHASED AND PERFORATE 9018.5' - 9051' PER HES JEWELRY LOG DATED 08-SEPT-2019. REFERENCE LOG DEPTH = 9018.5' - 9051'. CCL OFFSET = 8 FT. CCL STOP DEPTH = 9010.5 FT. POOH AND CONFIRM ALL SHOTS FIRED LAY DOWN FOR NIGHT SECURE WELL CONTACT DSO - DEPART LOCATION RIH W/ GUN #1 - 2.875" HSC MAXFORCE GUN , 6 SPF, 60 DEG PHASED AND PERFORATE 8987' - 9018.5' RIH W/ GUN #2 - 2.875" HSC MAXFORCE GUN , 6 SPF, 60 DEG PHASED AND PERFORATE 9018.5' - 9051' Daily Report of Well Operations PBU 11-07 6/30/2023 ARRIVE ON DS11-07 START PERMIT/JSA PRE JOB MEETING PU LUB WITH GUN #3 P/T LOW-300PSI, HIGH-3000PSI RIH W/ GUN #3 - 2.875" HSC MAXFORCE GUN , 6 SPF, 60 DEG PHASED AND PERFORATE 9051' - 9083.5' PER HES JEWELRY LOG DATED 08-SEPT-2019. REFERENCE LOG DEPTH = 9051' - 9083.5'. CCL OFFSET = 8 FT. CCL STOP DEPTH = 9043 FT. POOH AND CONFIRM ALL SHOTS FIRED RIH W/ GUN #4 - 2.875" HSC MAXFORCE GUN , 6 SPF, 60 DEG PHASED AND PERFORATE 9083.5 - 9127' PER HES JEWELRY LOG DATED 08-SEPT-2019. REFERENCE LOG DEPTH = 9083.5 - 9127. CCL OFFSET = 8 FT. CCL STOP DEPTH = 9075.5 FT. POOH AND CONFIRM ALL SHOTS FIRED RIG DOWN ALL EQUIPMENT SECURE WELL CONTACT DSO - CLOSE PERMIT DEPART LOCATION 7/1/2023 T/I/O= 2090/-15/-10 (PERFORATING) Flushed TBG by pumping 124 bbls of 1% KCl followed by 38 bbls of Crude as a freeze protect. Valve Positions - SV/WV/SSV= Closed, MV= Open, IA/OA=OTG FWHPs= 878/-14/-8 7/2/2023 CONTACT DSO, ARRIVE @ DS11-07, PERMIT/JSA P/U INTERWELL HEX 3.63-700 PLUG, TOOLSTRING- CH/3.125''CCL/X- OVER/INTERWELL SETTING TOOL/3.63'' HEX PLUG SET HEX PLUG @ MIDDLE ELEMENT 9137.3', POOH SECURE WELL, RIG DOWN RIH W/ GUN #4 - 2.875" HSC MAXFORCE GUN , 6 SPF, 60 DEG PHASED AND PERFORATE 9083.5 - 9127' RIH W/ GUN #3 - 2.875" HSC MAXFORCE GUN , 6 SPF, 60 DEG PHASED AND PERFORATE 9051' - 9083.5' SET HEX PLUG @ MIDDLE ELEMENT 9137.3', POOH Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 07/28/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230728 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU-23 50133206350000 214093 7/16/2023 HALLIBURTON PPROF BCU-24 50133206390000 214112 7/15/2022 HALLIBURTON PPROF BRU 223-34 50283201880000 223041 7/9/2023 HALLIBURTON RMT3D KBU 23X-6 50133203710000 184109 6/22/2023 HALLIBURTON EPX KBU 23X-6 50133203710000 184109 6/22/2023 HALLIBURTON MFC KGSF 7A 50133205380100 204163 6/18/2023 HALLIBURTON EPX KGSF 7A 50133205380100 204163 6/18/2023 HALLIBURTON MFC KU 21-6RD 50133100900100 201097 6/24/2023 HALLIBURTON EPX KU 21-6RD 50133100900100 201097 6/24/2023 HALLIBURTON MFC MPU B-24 50029226420000 196009 7/24/2023 HALLIBURTON WFL-TMD3D MPU B-34 50029235690000 216139 7/23/2023 HALLIBURTON WFL-TMD3D MPU B-50 50029232400000 204252 7/21/2023 HALLIBURTON WFL-TMD3D MPU E-23 50029225700000 195094 6/17/2023 HALLIBURTON COILFLAG MPU F-17 50029228230000 197196 7/2/2023 HALLIBURTON COILFLAG MPU L-13A 50029223350100 223017 6/21/2023 HALLIBURTON COILFLAG MPU L-39B 50029227860200 223037 6/30/2023 HALLIBURTON COILFLAG MPU L-39B 50029227860200 223037 6/30/2023 HALLIBURTON RBT PBU 11-07 50029206870000 181177 6/28/2023 HALLIBURTON RMT3D SCU 42-05X 50133205610000 206074 6/20/2023 HALLIBURTON EPX SCU 42-05X 50133205610000 206074 6/20/2023 HALLIBURTON MFC SCU 42-05Z 50133206950000 220069 6/16/2023 HALLIBURTON EPX SCU 42-05Z 50133206950000 220069 6/16/2023 HALLIBURTON MFC Please include current contact information if different from above. T37886 T37887 T37888 T37889 T37889 T37890 T37890 T37891 T37891 T37892 T37893 T37894 T37895 T37897 T37898 T37898 T37899 T37900 T37900 T37901 T37901 PBU 11-07 50029206870000 181177 6/28/2023 HALLIBURTON RMT3D Kayla Junke Digitally signed by Kayla Junke Date: 2023.08.01 10:05:02 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO. JiM Regg DATE: Wednesday, November 24, 2021 P.I. Supervisor��'l6'� ZI -7�C'�'72rz✓r SUBJECT: Mechanical Integrity Tests l(/ Hilcorp North Slope, LLC 11-07 FROM: Bob Noble PRUDHOE BAY UNIT 11-07 Petroleum Inspector Src: Inspector Reviewed B�� P.I. Supry NON -CONFIDENTIAL Comm I Well Name PRUDHOE BAY UNIT 11-07 Insp Num: mitRCN211112164131 Rel Insp Num: API Well Number 50-029-20687-00-00 Inspector Name: Bob Noble Permit Number: 181-177-0 Inspection Date: 1112/2021. Wednesday, November 24, 2021 Page 1 of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min - 11 07 Well T e In' w YP J - - TVD 8t37 � Tubing � 1825 � Is23 ts28 �' 1834 ' - PTD T e Test sem' "Test Yp P sl 1I 2034 [A 884 2597 2554 2543 rr --1811770_ X44 -- 1 - -- " BBL Pumped: 1.6 BBI. Returned: 1 3 - OA 65 234 230 -- -p- L -� - — - -- - l Interval ----1 --- REQVAR !P/F -- - -- P Notes' 2- Year MIT -IA to greater of Max injection psi or 0.25 x packer TVD per AA AIO 4G.009. (Header pressure = 1900 psi) Wednesday, November 24, 2021 Page 1 of 1 Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday, January 1, 2020 10:06 AM To: Wallace, Chris D (CED); AK, OPS EOC Specialists; AK, OPS FS2 DS Ops Lead; Ak, OPS FS2 Facility PTL; Ak, OPS FS2 Field PTL; AK, OPS FS2 OSM; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Alatalo, Travis; G GPB FS2 Drillsites; Rupert, C. Ryan Cc: Regg, James B (CED); AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Obrigewitch, Beau; Smith, Travis T (CONOCOPHILLIPS); Sternicki, Oliver R, Tempel, Joshua; Worthington, Aras J Subject: OPERABLE: Injector 11-07 (PTD #1811770) AA for continued water injection with IA repressurization All, Injector 11-07 (PTD #1811770) was made Under Evaluation after it was identified to have anomalous inner annulus repressurization. The well passed an AOGCC witnessed MIT -IA to 2,708 psi on 11/16/19 proving the well has two competent barriers to formation. The State has given approval under AID 4G.009 for continued water only injection. The well is now classified as OPERABLE. Please respond with any questions. Andrew Ogg Well Integrity Engineer SP Global Wells Organization - Alaska Office: 907-659-8110 From: AK71SWQ0 Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday, Deate4kber 9, 2019 7:49 AM To: 'chris.wallace@alaska.<chris.wallace@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS FS2 DS Ops Lead <AKOP SOpsLead@bp.com>; Ak, OPS FS2 Facility PTL <AKOPSFS2FacilityPTL@bp.com>; Ak, OPS FS2 Field PTL <AKOPSF52FieIdPTLcom>; AK, OPS FS2 OSM <AKOPSFS20SM1@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp. >; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL OPSPCCEOCTL@bp.com>; Alatalo, Travis <Travis.Alatalo@bp.com>; G GPB FS2 Drillsites <ggpbfs2drillsites CC Rupert, C. Ryan <Ryan.Rupert@BP.com> Cc:'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>,GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CD elllntegri@bp.com>; AK, GWO Projects Well Integrity<AKDCProjectsWelllntegrityEngineer@bp.com>; AK, GWO SU ell Integrity <AKDCWeIIlntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgw ellintegritywe@bp.com: AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsu ervice@bp,com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempseyl@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; Smith, Travis T (CONOCOPHILLIPS) <travis.smithl@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J MEMORANDUM TO: JimRegg P.I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, December 17, 2019 SUBJECT: Mechanical Integrity Tests HP Exploration (Alaska) Inc. I1-07 FROM: Jeff Jones PRUDHOE HAY UNIT 11-07 Petroleum Inspector Ste: Inspector Reviewed By: P.I. Supry ':J�R-- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 11-07 API Well Number 50-029-20687-00-00 Inspector Name: Jeff Jones Permit Number: 181-177-0 Inspection Date: 11/16/2019 - Insp Num: mitJJ191212165147 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 11-07 Type Inj I w "TVD 1 8137 Tubing 1395 1395 1396 1396 " PTD 1811770 Type Test SPT Test psi 2034 IA 1051 2749 2711 27os BBL Pumped: 1 BBL Returned: 1.5 OA 211 396 - 386 344 Interval REQVAR P/F P Notes: MIT -]A post well work over to repair IAxOA communication; AA 4G.004. 1 lJZ Tela(.(E.O Ck 40A-L"joesq) / l+ r- �3(sl Iri JI31 0 S'.T—to— ulC�tlCGr�'er" C�iMlp lei 1l�Zo, Zol.�l` r Tuesday, December 17, 2019 Page 1 of 1 Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWelISiteEnginee@bp.com> Sent: Monday, December 9, 2019 7:49 AM To: Wallace, Chris D (CED); AK, OPS EOC Specialists; AK, OPS FS2 DS Ops Lead; Ak, OPS FS2 Facility PTL; Ak, OPS FS2 Field PTL; AK, OPS FS2 OSM; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Alatalo, Travis; G GPB FS2 Drillsites; Rupert, C. Ryan Cc: Regg, James B (CED); AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Obrigewitch, Beau; Smith, Travis T (CONOCOPHILLIPS); Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J Subject: UNDER EVALUATION: Injector 11-07 (PTD #1811770) Under Eval clock reset to pursue AA All, Injector 11-07 (PTD # 1811770) was made Under Evaluation on 11/11/19 for exhibiting anomalous inner annulus repressurization after a Rig Workover. On 11/16/19 DHD performed a passing state witnessed MIT -IA to 2,708 psi. BP is pursuing Administrative Approval for continued water injection and the State has given approval to keep the well on water only injection while the AA process is carried out. The well remains classified as UNDER EVALUATION. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization - Alaska Office: 907-659-8110 From: AK, GWDAUt.11integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Monday, Novem 1, 2019 12:17 PM To:'chris.wallace@alaska.gov ris.wallace@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS FS2 DS Ops Lead <AKOPSFS sLead@bp.com>; Ak, OPS FS2 Facility PTL <AKOPSFS2FacilityPTL@bp.com>; Ak, OPS FS2 Field PTL <AKOPSFS2FieIdPTL 0m>; AK, OPS FS2 OSM <AKOPSFS20SM1@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp. 11 >; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL OPSPCCEOCTL@bp.com>; Alatalo, Travis <Travis.Alatalo@bp.com>; G GPB FS2 Drillsites <ggpbfs2drillsiteP.com>; Richards, Meredyth <Meredyth.Richards@bp.com>; Rupert, C. Ryan <Ryan.Rupert@BP.co Summers, Matthew <Matthew.Summers@bp.com> Cc:'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, GWO letions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWelllnte ' bp.com>; AK, GWO Projects Well Integrity<AKDCProjectsWelllntegrityEngineer@bp.com>; AK, GWO SUPT Well Inte <AKDCWelllntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellinte ' we@bp.com, AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service com> Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dem pseyl@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Obrigewitch, Beau MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Thursday, December 5, 2019 2 _ P.I. Supervisor t �� ��bll� SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. 11-07 FROM: Lou Laubenstein PRUDHOE BAY UNIT 11-07 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry -Ii 77- NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 11-07 API Well Number 50-029-20687-00-00 Inspector Name: Lou Laubenstein Permit Number: 181-177-0 Inspection Date: 11/4/2019 Insp Num: mitLOL191105104832 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 11-07 Type Inj I N ' TVD 1 8137 Tubing -2 ' 0 0 o PTD 1811770 Type Test SPT Test psi 3000 IA 2021 3243 ' 3220 - 3216 ' BBL Pumped: IBBL Returned: OA -1 58 53 51 Interval OTHER P/F P Notes: MIT -IA pre Injection test, per Sundry 319-377 ✓ Thursday, December 5, 2019 Page I of 1 Wallace, Chris D (CED) From: Wallace, Chris D (CED) Sent: Thursday, December 5, 2019 2:47 PM To: AK, GWO Well Integrity Engineer Cc: Regg, James B (CED); Smith, Travis T (CONOCOPHILLIPS); Sternicki, Oliver R, AK, GWO SUPT Well Integrity Subject: RE: Request to keep Injector 11-07 (PTD #1811770) online during AA request Andrew, Keep the well on water injection and we can look at getting the AA sorted in the very near future. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7`^ Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace(@alaska ¢ov CONFIDENTIALITY NOTICE. This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.aov. From: AK, GWO Well Integrity Engineer <AKGWOWeIISiteEnginee@bp.com> Sent: Thursday, December 5, 2019 2:19 PM To: Wallace, Chris D (CED) <chris.waIlace @alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Smith, Travis T (CONOCOPHILLIPS) <travis.smithl@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellintegrityCoordinator@bp.com> Subject: Request to keep Injector 11-07 (PTD #1811770) online during AA request Mr. Wallace, Produced Water Injector 11-07 (PTD #1811770) currently operates under AID 4G.004 for IAxOA communication. The well failed an AOGCC MIT -IA in March of 2019 and the decision was made to perform a rig work over which was completed on 10/26/19. As part of the rig workover, a new 7" casing tie -back string was installed to ensure production casing integrity and a new production tubing string was used to complete the well. Prior to placing the well on injection, an AOGCC witnessed MIT -IA passed to 3,216 psi and MIT -T passed to 2,671 psi on 11/04/19. The well was placed on Injection on 11/06/19 and shortly thereafter was made Under Evaluation on 11/11/19 after it exhibited anomalous Inner Annulus repressurization. While the well was online, an AOGCC witnessed MIT -IA was performed and passed to 2,708 psi on 11/16/19 confirming the well has two competent barriers to formation. Based on the passing MIT -IA, BP plans to pursue Administrative Approval for continued operation with TxIA communication. Because the rig workover has remedied the IAxOA communication, BP plans to submit a cancellation request of AID 4G.004 and then apply for Administrative Approval for continued injection with TxIA communication. BP is requesting your approval to continue injection on 11-07 while the aforementioned plan of canceling AID 4G.004 and seeking Administrative Approval is carried out. Please respond at you earliest convenience. Andrew Ogg STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPFRAT1nNR Nnu i 1 )non Forth 10404 ReNsed 04/2017 ll l'(zj�j O'�� IBDMS HF" NOV 2 2 2019 Submit Original Only 1. Operations Performed �. Abandon 11 Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing RI Operati� 6ngyoWr• _� ❑ Suspend ❑ Perforate 4 Other Stimulate ❑ Alter Casing 0 Change Approved Program ❑ Plug for Rednll ❑ Perforate New Pool ❑ Repair Well m Re-enter Susp Well ❑ Other: ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development ❑ Exploratory ❑ 5. Permit to Drill Number: 181-177 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service 21 6API Number: 50-029-20687-00-00 7 Property Designation (Lease Number): ADL 028325 8. Well Name and Number: PBU 11-07 9. Logs (List logs and submit electronic and pdnted data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 9472 feet Plugs measured None feet true vertical 8986 feet Junk measured 9270 feet Effective Depth: measured 9432 feet Packer measured 8415, 8586, 8751 feet true Vertical 8948 feet Packer true vertical 7982.8146.8303 feet Casing: Length: Size: MD: TVD: Burst Collapse: Structural Conductor 80 20" 32-112 32-112 1490 470 Surface 2627 13-3/8" 32-2659 32-2659 5360 2670 Intermediate 8237 9-5/8" 50-8287 50-7861 6870/8150 4760/5080 Tieback Liner 8039 T' 30-8070 30-7659 7240 5410 Liner 1380 7' 8092-9472 7680-8986 7240 5410 Perforation Depth: Measured depth: 9150-9312 feet True vertical depth: 8681 -8835 feet Tubing (size, grade, measured and true vertical depth) 4-1/2' 12.6# 13Cr85 / L-80 28 - 8674 / 8751 - 87 28 - 8230 / 8303 - 832 Packers and SSSV (type, measured and 4-1/2" HES TNT Perm Packer 8415 7982 true vertical depth) 4-1/2" Baker S-3 Packer 8586 8146 4-1/2" TIW HBBP Packer 6751 8303 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Shut -In Subsequent to operation: 7625 622 0 14.Attachments: (re9uiied per 20 mac 25,070 25,071. a 25.253) 15, Well Class after work: Daily Report of Well Operations RI Exploratory ❑ Development ❑ Service El Stretigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Sfimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG 0 GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knov4edge. Sundry Number or N/A if C.O. Exempt: 319-377 Authorized Name: Lastufka, Joseph N Contact Name: Hyatt, Trevor Authorized Title: (SIP&PecialiltContact Email: Trevor.Hyattflbp.com Authorized Signature: Data: 1 Contact Phone: +1 907 564 4627 Forth 10404 ReNsed 04/2017 ll l'(zj�j O'�� IBDMS HF" NOV 2 2 2019 Submit Original Only T/I/O = SSV/0/0 TEMP = SI, PPPOT-IC (LPE) PPPOT-IC: Assist DHD while with (LPE). Sting into IC test void 0 psi on void. Stay stung into test void while (DHD) pressure up OA to 500 psi. No change in IC test void pressure. 4/11/2019 (DHD) pressure IA to 2,500 psi. IC test void stayed at 0 psi while (DHD) continued testing. T/I/O = Vac/20/Vac. Temp = SI. MIT-IA PASSED to 2500 psi, Max Pressure = 2500 psi, Target Pressure = 2300 psi (eval IAxOA). IA FL @ surface & OA FL @ near surface. Used 2.4 bbls of DSL to increase OAP from a Vac to 500 psi. During OA increase IAP increased 21 psi. Used 2.2 bbls of DSL to pressure up IAP from 41 psi to 2500. On the third test, IAP lost 4 psi in the 1st 15 minutes and 3 psi in the second 15 minutes for a total loss of 7 psi in 30 minutes. During MIT-IA, OAP increased 15 psi. Bled IAP to 10 psi (4.5 bbls). Bled OAP to 4 psi ( 0.5 bbls). During rig down IAP increased to 30 psi and OAP increased to 20 psi. Hung tags. Final WHPs = 180/30/20. 4/11/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 14:15 ***WELL S/I ON ARRIVAL SWCP 4518***(leak deletion log) PULL P-PRONG FROM 8638' SLM 6/14/2019 ***CONTINUE WSR TO 6/15/19*** ***CONTINUE WSR FROM 6/14/19 SWCP 4518***(leak detection log) PULL 4-1/2" PX PLUG BODY FROM 8642' MD RAN 26DUMMY PERF GUN DRIFT TO 9260' SLM(9263' MD) NO SAMPLE. 6/15/2019 ***WELL S/I ON DEPARTURE*** T/I/O = SSV/0/0 TEMP = SI, PPPOT-T (PASS) PPPOT-IC (PASS) Pre Rig PPPOT-T: Stung into test void 60 psi on void, bled to 0 psi. Monitored for 15 min, no change in pressure. Function (LDS), torque back to 400 ft/lbs. R/U test equipment. Pump thought test void, good returns of fluid. Shut in pump, pressure to 5,000 psi for 30 min test. Lost 100 psi in 15 min, lost 30 psi in second 15 min (PASS). Bleed to 0 psi R/D test equipment. PPPOT-IC: Stung into test void 10 psi on void, bled to 0 psi. Monitored for 20 min, no change in pressure. Function (LDS), torque back to 400 ft/lb. R/U test equipment, Pump 8/5/2019 though test void, clean fluid returns. Pressure test void to 3,500 psi for 30 min test. Lost 100 ***WELL SHUT IN ON ARRIVAL*** PERFORM JEWELRY LOG FROM TD TAG AT 9275' TO 8400'. PERFORATE 9205'- 9225' WITH 2.875" MAXFORCE GUNS, 6 SPF, 60 DEG PHASE. CCL TO TOP SHOT = 4.0', CCL STOP AT 9201'. CORRELATE TO COMPOSITE LOG DATED 23-JUL-19. 9/8/2019 ***JOB CONTINUES ON 09-SEP-19 WSR*** ***JOB CONTINUES FROM 09-SEP-19 WSR*** PERFORATE FROM 9150'- 9175' WITH 2.875" MAXFORCE, 6 SPF, 60 DEG PHASE. CORRELATED TO COMPOSITE LOG DATED 23-JUL-19 9/9/2019 ***JOB COMPLETE, WELL SHUT-IN ON DEPARTURE, DSO NOTIFIED*** ***WELL S/I ON ARRIVAL`**(rwo) DRIFTED 3.805" G-RING TO 8660' SLM SET 4 1/2" PX-PLUG BODY @ 8626' SLM (8642' MD) SET 96" P-PRONG IN PLUG BODY @ 8626' SLM LRS PERFORM PASSING MIT-T 9/11/2019 ***LRS IN CONTROL OF WELL ON DEPARTURE, DSO NOTIFIED OF STATUS*** T/I/O = 350Nac/0. Temp= SI. Tbg _&IA FLs (SL request). TFL @ 1180' (18 bbls). IA FL @ near surface. 9/11/2019 ISLB SL in control of well on arrival. 1140 hrs. Daily Report of Well Operations PBU 11-07 T/1/0=346/0/0 Temp= S/I (LRS Unit 76- Assist Slickline: MIT-T's/ RWO Capital) MIT-T passed to 3066 psi. Max applied=3250 psi. Target Pressure= 3000 psi. Pressure up TBG to 3235 with 22 bbls diesel. 1 st 15 min TBG lost 125 psi. 2nd 15 min TBG lost 44 psi for a total loss of 169 psi in 30 min. Bled TBG to 2000 psi and recovered .5 bbls. MIT-IA passed to 3165 psi. Max applied=3250 psi. Target Pressure= 3000 psi. Pressure up IA to 3221 with 6.23 bbls diesel. 1 st 15 min IA lost 41 psi. 2nd 15 min IA lost 15 psi for a total loss of 56 psi in 30 min. Bled IA to 2000 psi and recovered 2.7 bbls. 9/11/2019 ***WSR Continued on 09-12-2019*** **`WSR Continued from 09-11-2019*** (LRS Unit 76 - MIT-OA) MIT-OA PASSED to 2918 psi. Max applied=3000 psi. Target Pressure= 2900 psi. Pressure up OA to 2990 with .44 bbls diesel. 1st 15 min OA lost 21 psi. 2nd 15 min OA lost 19 psi for a total loss of 40 psi in 30 min. test. Bled OA to 5 psi and recovered 2.42 bbls. WSL notified. Hung tags on WV,IA and OA. AFE sign on MV ***FLUID PACKED WELL*** Valve 9/12/2019 positions=SV.WV,SSV closed MV Open CV'S OTG T/I/O = 440/2/10. Temp = SI. TBG FL (E-line Request). TBG FL @ near surface. 9/16/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 05:00 ***JOB START 16-SEPT-2019 (SLB ELINE) PUNCH TUBING @ 8499'- 8405' W/ 5 FT 4 SPF 0 DEG PHASING, CCL TO TS = 5.625', CCL STOP DEPTH = 8493.4' RUN IN HOLE WITH PUNCHER, CORRELATE TO 4.5" TUBING TALLY DATED 9/16/2019 4/16/2008 **JOB CONTINUED FROM 09-17-19 (SLB ELINE)** T/1/0=322/0/0 CUT TUBING @ 8510' W/ RCT CUTTER, CCL TO MIDDLE OF CUTTER=14.7', CCL STOP DEPTH=8495.3' INDICATION THAT TUBING CUT SUCCESSFULLY 9/17/2019 *** WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED*** T/1/0=275/0/0 (LRS Unit 76 - CMIT-TxIA Post Tubing Cut, Circ Out) Freeze protect FL w/ 6 bbls 60/40. CMIT-TxIA FAILED (2 attempts made) (Max Applied=3250 psi Target =3000 psi) Pump 14 bbls to catch pressure. Pump an additional 9 bbls to reach test pressure. 1st 15 min T/IA Loss of 474/471 Estimated LLR of 2.50 GPM between 2 tests Pump the following down the tubing, taking returns up the IA, to 11-12's flowline: 878 bbls 9.8 ppg NaCl Brine. Freeze protect W/ 18 bbls Diesel. U-Tube FP into IA. Did not Freeze Protect 11-12's Flowline. DSO to POP. Notified DSO. Valve Positions=SV,WV,SSV closed MV open CV's OTG 9/18/2019 FWHP=435/444/610 T/I/O =- VAC/0/0. (Pre CDR2) RU Lubricator 68-840 w/ 4" CIW BPV #281. Set BPV at 9/26/2019 125". *** Job Complete *** Final WHPs T/1/0= Vac/0/0 T/I/O=BPV/0/0 Pre CDR 2. RID production tree, R/U Dryhole tree Temp #66. Torqued to API specs. PT'd against Master valve through tree cap, 300/low..5000/high.. 5 min. each... 9/28/2019 Pass. see "Field Charted Tests" FWP's BPV/0/0 see log for details. T/I/O=BPV/O/O. Pulled 4" H BPV #281 @ 105". ***Job Complete***. See log for details. 10/6/2019 FWHP=Vac/0/0. T/I/O = Unk/Vac/Vac. Temp = SI. WHPs (Pre RIG). No wellhouse, scaffold, flowline. ISV Dryhole tree installed. Unable to access tree cap. 10/13/2019 = C. MV = 0. IA, OA = OTG. 1500 hrs. Daily Report of Well Operations PBU 11-07 T/1/0=0/0/0 PRE RIG R/D OA tapped blind & install intagral flange. Torqued integral flange to 543 ft lbs. Installed block valve and 1502 cap. R/D IA tapped blind & install intagral flange. Torqued intagral flange to 188 ft lbs. Installed block valve and 1502 cap. 10/14/2019 PT'd IA & OA Low 300psi, High 3500psi. RDMO ***Job Complete*** FWHP =0/0/0 T/I/O = ONac/200. Temp = SI. IA FL (Rig Request). IA FL @ 90'(4.8 bbls). 10/17/2019 CDR -2A in control of well upon departure. 18:30 North America - ALASKA- BP Page 1 of 11 Operation Summary Report Common Well Name: 11-07 AFE No Event Type. WORKOVER (WO) Start Date: 10/16/2019 End Date: 10/26/2019 H-S4DW0019H9-EX-Dl-WO- (2,144,872.00) Protect: PBU Site: 11 Rig Name/No.: CDR-2 Spud Dat.7ime: 8/3/1992 12:00 OOAM Rig Release: 10/26/2019 Rig Contractor: NABORSALASKA DRILLING INC. BPUOI: USA00001218 Active datum: KB @62.00usft (above Mean Sea Level) Date From -To Hrs Task I Code NPT Total Depth Phase Description of Operations (hr) _ (usH) 10/16/2019 20:30 - 22:30 2.00 MOB ~ I P _ _ _ PRE MOVE RIG FROM TARMAC TO DS11 22:30 - 00:00 1.50 MOB P PRE ARRIVE LOCATION j REMOVE JEEPS VERIFY PRESSURES ON IA/OAZERO j LINE UP SUB FOR MOVE OVER. INSTALL '00:00 FOOT 10/17/2019 - 02:00 2.00 MOB P PRE - FINISH SPOTTING RIG --.—� RIG ACCEPTED AT 02:00 102:00 - 06:00 4.00 MOB P I _ PRE _ iPJSM, PERFORM RU CHECKLISTS 06:00 - 10:00 4.00 MOB 1 P _ PRE RIG UP HARDLINE IN CELLAR FOR PUMPING DIESEL OUT OF WELL. RIG MANAGER AND WSL REVIEW VALVE j CONFIGURATION AGAINST HAZOP P81D. j PRESSURE TEST HARDLINE TO 3500 PSI, .,GOOD. 10:00 - 12:00 2.00 MOB PPRE _ RIG EVAC DRILL WITH WARD CREW. CONDUCT AAR AFTERWARDS. — T —F L REVIEW WELL PLAN WITH WARD CREW .12:00 - 15.00 3.00 � MOB � P PRE RIG EVAC DRILL WITH BEARD CREW, AND I REVIEW WELL PLAN. PJSM FOR PUMPING OUT DIESEL. j'. COMPLETE VALVE CHECKLIST. REVIEW VALVE LINEUPS WITH TOOLPUSHER, 15:00 - 16:30 1.50 MOB � P _ DRILLERAND WSL. PRE NO PUMPS. VFD NEEDS RESET, GET (ELECTRICIAN TO RIG. RESET VFD, START PUMPING. NO SIGN OF ANY RETURNS, INCREASE RATE TO 2 BPM. CHECK LINEUPS AGAIN, STILL GOOD. SHUT DOWN AND PURGE TT LINE WITH AIR, CLEAR. j CHECK OA PRESSURE, 0 PSI. ' RESTART PUMP( NG38PM /50 PSI. NO I16:30 - 18:00 1.50 MOB P 4 RETURNS. PRE ,AFTER 130 BBLS AWAY, NO RETURNS, NO 'PRESSURE ON TUBING OR PUMP. j SHUT DOWN AND DISCUSS WITH ODE, -__4—�— --.. 18:00 - 00:00 6.00 MOB P� __WSUP. PRE DHD SHOT FLUID LEVEL ON IA. 90' - CALL WSUPT, WOS. COME BACK ONLINE DOWN IA TAKING RETURNS TO TUBING -RETURNS FROM TUBING AT 6 BBLS AWAY �DOWN IA. (IA VOLUME=4.8 BBLS, TUBING 1.4 BBLS) - RETURNS ON THE TUBING 6.7 PPG FOR 5 BBLSAND WENT TO CONSISTENT 9.8 PPG. SHUT DOWN AFTER I2BBLS. - SWAP TO PUMPING DOWN TUBING. RETURNS COMING FROM IAARE ,COMMINGLED. - PUMPED A TOTAL OF 155 BBLS DOWN THE TUBING. CLEAN 9.B PPG COMING OUT. - BEGIN U-TUBING WELL PRIOR TO FLOW 'CHECK. — — —_ - PERFORM FLOW CHECK. CREW CHANGE Printed 11/20/2019 12:37:34PM **All depths reported in Drillers Depths** North America - ALASKA - BP Page 2 of 11 Operation Summary Report Common Well Name: 11-07 - - - - -- - - AFE No -- _ - Event Type: WORKOVER (WO) Start Date: 10116/2019 iEnd Date: 10/26/2019 H-S4DW0019H9-EX-DI-WO-(2,144,872.00) Project: PBU Site: 11 Rig Name/No.: CDR -2 Spud Date/Time: B/3/1992 12:00:OOAM ele Rig Rase: 10/26/2019 Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00001218 Active datum: KB @62.00usft (above Mean Sea Level) Date I From - To Him Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 10/18/2019 00:00 - 01:30 1.50 MOB P �— PRE FLOWCHECK - BOTH TUBING AND IA DEAD FOR 30 MINUTES - REMOVE HARDLINE OFF TUBING _ - PJSM W/ CAMERON REP. T -BAR HP BPV IN 01:30 - 02:00 0.501 MOB P �— PRE HP BPV ROLLING TEST PUMP 4.3 BBLS DOWN IA TO CATCH FLUID (63') - SET MPD PRESSURE AT 500#. MAINTAINED 1FOR 8MINUTES. PUMP BARELY STROKING. I 0.7 BBLS OVER THE 8 MINUTES I- LIQUID LEAK RATE IN LINE WITH LRS LEAK RATE ON 18 -SEPT -2019 THROUGH CASING LEAK —-�—r - BPV SHOWED NO SIGN OF LEAKAGE. _ GOOD TEST —PRETI�A 02:00 03:30 1.50 MOB P _ PJSM, RE -RIG HARDLINE IN CELLAR TO FACILTATE HOLE FILL FROM FRONT. 1 - RIG UP TO OA FOR EXTENDED NO -FLOW � CHECK - CLEAR REAR OF CELLAR TO FACILITATE TREE NIPPLE DOWN AND BORE NIPPLE UP. '- PERFORM LTT ON IA RIG UPS TO 3500#. 0330 - 06:00 2.50 MOB PI GOOD TEST PRE PJSM, W/ CAMERON FOR PULLING TREE 1-VERIFYIADEAD, EVACUATE TREE DOWN TO BPV. -CAMERON VERIFIED NO PRESSURE IN HANGER VOID. :-REMOVEALLBUT4NUT. BREAKSEALON TUBING ADAPTER FLANGE. -REMOVE DRY HOLE TREE AND TUBING ADAPTER FLANGE. '.- CHECK HANGER THREADS WITH 4-1/2"TCII, GOOD THREADS 7-1/4 TURNS. t- -- PJSM FOR RIGGING UP BOPS. 12.50 BOPSUR -�- P 06:00 - 18:30 PRE RIG UP BOPS IN CELLAR. BRING ANNULAR IN, BRING IN BLINDS WITH ANNULAR LIFT CRADLE. MAKE UP BLINDS. j PICK UP STACK WITH BRIDGE CRANE, MAKE UP FLOW CROSS THEN VERS. MAKE UP KILLAND CHOKE LINE VALVES ONTO FLOW CROSS. AT 07:00 FILL WELL DOWN IA WITH 3.8 BBLS. I AT 12:00 FILL WELL DOWN IA WITH 4.3 BBLS. ' 16:30 FILL WELL DOWN IA WITH 1.7 BBLS 16:30 - 00:00 5.50 BOPSUR P I i PRE PJSM, FOR INSTALLING ROPE ON WELLHEAD - PICK STACKAND TROLLEY OVER AND SET iDOWN. - MAKE UP STUDS AND TORQUE -21:30 FILLL WELL DOWN IA WITH 1.3 BBLS - WORK ON GETTING CHOKE AND KILL LINES 10/19/2019 00:00 - 05:30 550 BOPSUR P RIGGED UP PRE 1BOPE STACK 1 - CONTINUE WORKING ON GETTING KILL LINE RIGGED UP. - INSTALL KOOMEY LINES ON STACK i I -� -HOUSEKEEPING IN CELLAR AFTER STACK BUILD. Printed 11/20/2019 12:37:34PM **All depths reported in Drillers Depths" North America -ALASKA - SP Page 3 of 11 Operation Summary Report Common Well Name. 11-07 _ AFE No Event Type: WORKOVER(WO) ;Start Date: 10/16/2019 End Date: 10/2612019 H-S40W0019H9-EX-DI-WO-(2,144,872.00) Project: PBU Rig Name/No.. CDR -2 Spud DateRme, 6/3/1992 12:00:OOAM Rig Release: 10/26/2019 Rig Contractor: NABORS ALASKA DRILLING INC. BPUO1: USA00001218 Active datum: KB @62.00usR (above Mean Sea Level) Date From - To Hrs Task Code NPT I Total DFepth Phase Description of Operations _ (hr) i (usft) -05:30 - 12:00 6.50 BOPSUR P� PRE ENERGIZE O RSHUTCN, LEAKS. OPEN UP OAAT O600U ON VAC, WILL CHECK IT EVERY HOUR. AT 07:00 FILL IA WITH 4.5 BBLS. BRING XO AND HANDLING EQUIPMENT TO RIG FLOOR. CHASE LEAKS ON ACCUMULATOR SYSTEM. GREASE STACKAND CHOKE. INSTALLAIR BOOT ON RISERAND ENERGIZE. SERVICE TOP DRIVE. — AT 12:00 FILL IA WITH 0.7 BBLS 12:00 - 20:30 8.50 BOPSUR P PRE BRING RIG TONGS TO FLOOR, RIG UP TORQUE I BRING TEST JOINTS TO FLOOR. FUNCTION TEST BOPS. MEASURE TEST JT IN 21 FTAND FUNCTION VBRS AND ANNU LAR. i TORQUE UP XO ON TEST JOINTS, REVIEW RIG TONG OPERATION AND TORQUE VALUES WITH CREWS. AT 16:15 FILL WELL WITH 5.4 BBLS DOWN IA. 'COMPLETE VALVE CHECKLIST. FLUID PACKING WELL FOR SHELL TEST. PERFORM 250# LOW/ 5000# HIGH SHELL 'TEST j RUN RAM LOCKS IN. LITTLE WATER ON. CONNECTION BETWEEN BLINDS AND MUD I CROSS RE -TORQUE �— 20:30 - 00:0-07-3,55-7 BOPSUR P PRE IN ITIAL SOPE TEST PER BP AND AOGCC STANDARD. TEST WITNESSED BYAOGCC AUSTIN McLEOD '— 13-5/8" ANNULAR, BLIND, MUD X, 4-1/2" x 7" VARIABLE. ANNULAR TESTED TO 250 PSI LOW / 3500 PSI HIGH FOR 5 MIN EACH - RAMS / VALVES TESTED 250 PSI LOW / 5000 PSI HIGH FOR 5 MIN EACH j - TEST 1: BLINDS ON RAM LOCKS, BL2, R2, C11, C16, TV2 PASSED - TEST2: 81, C15 PASSED - TEST 3: B2, B4 PASSED -TEST 4: B3 PASSED ',. -INSTALLED 4-1/2" TEST JOINT, CLOSE RAMS. STRIP UP TO TAG. ATTEMPTTO PUT ON RAM LOCKS. RAMS LOCKS NOT !,WORKING. Printed 11/20/2019 12:37:34PM **All depths reported in Drillers Depths"' North America -ALASKA - BP Page 4 of 11 Operation Summary Report Common Well Name: 11-07- - - - - - - - --- - - _ - - - -- AFE No Event Type: WORKOVER(WO) ,Start Date. 10/16/2019 IEnd Date: 10/26/2019 H-S4DW0019H9-EX-DI-WO-(2,144,872.00) Project: PBU Site: 11 Rig Name/No.: CDR-2 Spud Daterrime: 8/3/1992 12:00:00AMRig Release: 10/26/2018 Rig Contractor: NABORSALASKA DRILLING INC. BPUOI: USA00001218 Active datum: KB Q62.00usR (above Mean Sea Level) Date From -To Hm Task Code NPT Total Depth Phase Description of Operations _ (hr) (usft 10/20/2079 0000 - 07:00 7.00 BOPSP PRE TEST C7, C9, C10 PASS WHILE TROUBLESHOOTING RAM LOCKS. TEST 6: VARIABLES (4-1/2") HYDRAULIC IBOP, C5, C6, Ce, TV1 PASS TEST 7: CHOKE A, CHOKE C PASS TEST 8: LOWER IBOP, C1, C4 PASS TEST 9: TI W, C2, C3 PASS TEST 10: ANNULAR (4-1/2") 3500# GOOD TEST I '.PERFORM ACCUMULATOR DRAWDOWN 3000 PSI START 31 SEC TO 200 PSI / 99 SEC TO 'FULL RECHARGE LAY DOWN 4-1/2" TEST JOINT, MAKE UP 7" TEST JOINT ' FILL HOLE WITH 10 BBLS AT 0300. MAKE UP 7" TEST JOINT. TEST 11: VBR, DART VALVE PASS j TEST 12: ANNULAR (7) PASS -- 'TEST 13_C9_C10 BACKWARDS PASS 0700 - 13:006 6.00 BOPSUR N PRE TEST VBR RAM LOCKS AGAIN WITH 7". CLOSE RAMS WITH 2000 PSI CLOSING PRESSURE. ! BLEED PRESSURE IN THE CLOSED POSITION I AND ENGAGE MANUAL STEM LOCKS. 'USE PROCEDURE FROM HYDRIL TO TEST MANUALLOCKS. VBRS NOT HOLDING LOW PRESSURE ON LOCK TEST, FLUID IS SEEN BYPASSING. DISCUSS WITH HYDRIL TECH IN AND. AT 09:00 FILL IA WITH 1.0 BELS. CONTINUE TROUBLESHOOT VBR LOCKS. GETANOTHER PT ON VARIABLES WITH REGULAR ACCUMULATOR PRESSURE, HOLDING GOOD. 'TRY RAMLOCKTESTAGAM, USE BORESCOPE TO SEE IF RAMSARE OPENING WHEN ACCUMULATOR PRESSURE IS BLED OFF. RAMSARE SEEN MOVING WHEN - i ACCUMULATOR PRESSURE IS BLED OFF, I WITH ZERO WHP. USE NEW PROCEDURE FROM HYDRIL, PUT .300 PSI WHP ON RAMS THEN BLEED OFF ACCUMULATOR PRESSURE. HOLDS 300 PSI WHP. GO To 5K, GOOD. 13:00 - 21:00 8.00 PULL P DECOMP UD TE ST JOINTS. CLEAR FLOOR, PREP TO PULL HANGER. AT 14:00 FILL IA WITH 7.8 BELS. EVACUATE STACK. BREAKOFF TIWFROM TEST JOINT. . BRING DOYON EQUIPMENTTO RIG FLOOR. MAKE LANDING JO I PULL HANGER FREEAT 123 123K, K, PU i WEIGHT132K — LAY DOWN HANGER 21:00 - 0000 100 PULL P DECOMP PJSM, TOURPUSHER AND WSL WALKED LINE UPS -CLOSEANNULAR, BREAK CIRCULATION - PUMP 40 BBLS 9.8 BRINE BARACLEAN PILL - CIRCULATE 100° 9.8 PPG BRINE AT 160 SPM. _.�. - CONTINUE CIRCULATING Printed 11/20/2019 12:37:34PM **All depths reported in Drillers Depths** North America - ALASKA - BP Page s or 11 Operation Summary Report - - Common Well Name: 11-07 AFE No Event Type: WORKOVER(WO) Start Date: 10/1612019 End Date: 10/2612019 H-S4DW0019H9-EX-DI-WO-(2,144,872.00) Project: PBU I Site: 11 Rig Name/No.: CDR -2 Sputl DateRime: 8/3/1992 12:OO:OOAM Rig Release: 10/26/2019 Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00001218 Active datum: KB @62.00usR (above Mean Sea Level) _ - Date From - To Hrs Task II Code NPT Total Depth I Phase Description of Operations (hr) ustt) 10/2ate 00:00 - 02:30 2.50 PULL P DECOMP SURFACE TO SURFACE COMPLETED - PERFORM FLOW CHECK WHILE RU j REMAINING EQUIPMENT ON THE FLOOR BLOW DOWN TOP DRIVE, MAKEUPTIW WITH X -OVER. j - BRING ON HOLE FILL. j -PJSM. REVIEW STANDING ORDERS. _ AT1 TEMPT TO BREAKOUT TOP DRIVE 02 30 - 04:00 1.50 PULL p DECOMP TROUBLESHOOT TOP DRIVE (ELECTRICIAN TROUBLESHOOTING) 04:00 - 07:30 3.50 PULL P _ DECOMP IBREAKOUT, RUAIR SLIPS, DOYON TONGS - BEGIN PULLING COMPLETION i - AFTER 10 JTS OUT CONDUCT DI DRILL WITH WARD CREW. j -CREW M/U TIW TO JOINT IN STACKAND CHAIN TONGS IT UP. i - WELL IS SECURED IN 2 MIN 40 SEC, i - CONDUCT AAR WITH CREWS. CONTINUE UD 4-1/2" TCII COMPLETION. 7:30 - 08:30 1.00 PULL P I DECOMP AFTER 40 JTS RIG GOES DARK. FIELD WIDE POWER OUTAGE. j POWER COMES ON THEN GOES OFF i COUPLE TIMES. RAISE BLOCKS AND INSTALLTIW DURING THE TIMES POWER IS ON. WORK ON GETTING GENS STARTED. ONCE ON GEN POWER CONDUCTAAR FOR UNPLANNED POWER SWAP, CHECK RIG ~'08:30 — SYSTEMS. - 18:30 10.00 PULL _ _POWER _ DECOMP CONTINUE UD 4-1/2" TUBING, WILL STAY ON . GENS UNTILALL TUBING IS OUT. j '- LAID DOWN 204 JOINTS AND PARTIAL. SENT OUT PERFORATED JOINT#2, AND 3.75' OF JOINT#1. DRIFTED CUT WITH 3.833" DRIFT. I - DISCUSS WITH ODE. -- --; - - SERVICE TOP DRIVE, BRING IN I COMPLETION COMPONENTS. 1830 --213043.00 _ PULL P DECOMP PJSM, -- — -_ -- — IN HOLE WITH LOWER COMPLETION (RUN ASSEMBLY - ALL CONNECTIONS BELOWPACKER BAKER LOCKED. --til--til I tI p RIH ON 4-1/2" TCII WORK STRING. __. 30 00:00 2.50 PULL DECOMP CONTINUE RIH WITH WORKSTRING. 10/22/2019 00:00 11:30 11.50 RUNCOM P DECOMP CREW CHANGE OUT !CONTINUE WITH RUNNING LOWER COMPLETION ON WORK STRING. STAB TIW VALVEAT 05:30 THEN SWAP TO HI -LINE POWER. RIG GOES DARK MOMENTARILY. POWER UP RIG, CONTINUE RIH WITH ;COMPLETION. ON JOINT#194 SET DOWN, LIKELY LINER TOP. --_. Printed 11/20/2019 12:37:34PM "All depths reported in Drillers Depths— North America - ALASKA - BP Page 6 of 11 Operation Summary Report Common Well Name11-07 - - -- - _ -- -- - - -� AFE No - _- - Event Type: WORKOVER (WO) 1 Start Date: 10/16/2019 End Date: 10/26/2019 H-S4DWO019H9-EX-DI-WO- (2,144,872.00) Project: PBU _ - Site: 11 Rig Name/No.. CDR -2 Spud Dal 8/3/1992 12:00:OOAM Rig Release: 10/26/2019 Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00001218 Active datum: KB @62.00usft (above Mean Sea Level) Date From - To Hire I Task CodeNPT Total Depth Phase Description of Operations ! (hr) _ (usft 111:30 - 14:30 3.00 RUNCOM P T— DECOMP TOUR CHANGE AND PJSM WITH ROY CREW, HESANDBOTREP. PICKUP JT #194 ON ELEVATORS AND TRY TO EASE PAST LINER TOP. NO GO. MARK PIPE. UD JOINT #194 AND PICK UP XO FOR MAKE UP WORKSTRING TO TOP DRIVE. I TOP DRIVE TO JT #194. EASE DOWN TO JUSTABOVE MARKANO PUT 1 1/2 TURN TO LEFT. WORK PIPE THEN TRY TO PASS LINER TOP, NO GO. PUTANOTHER 1/2 TURN TO LEFTAND WORK IT DOWN. ABLE TO PASS LINER. TOP. 'CONTINUE M/U WORK STRING. GET UPAND DOWN WEIGHTS ON JT 4203. 1140K / 130K. M/U JT #204 THEN M/U TOP DRIVE TO WORK STRING. _ 14.30 - 1630 2.00 RUNCOM P DECOMP SET DOWN 10K THEN PICKUP 20K OVER, I GOOD INDICATION GRAPPLES IN CASING PATCH HAVE ENGAGED. SLACK OFFAND PICK UP SEVERAL TIMES THEN GO TO NEUTRAL WEIGHT. j 'LINE UP TO PUMP DOWN WORKSTRING. PUMP TO 250 PSI, BLEEDS OFF 5 PSI IN 5 MIN. 1. PUMP TO 980 PSI, BLEEDS OFF 15 PSI IN 5 1 MIN. ' BLEED OFF PRESSURE AND BREAK OFF TOP DRIVE. DROP BALLAND ROD, WAIT 9 MINUTES. PRESSURE UP TO 3000 PSI, HOLD FOR 2 MIN. - BLEED OFF TO 1500 PSI. TRAP PRESSURE IN WORKSTRING THEN - 1 j LINE UP TO PUMP DOWN IA. 1 PRESSURE UP TO 1200 PSI, BLEEDS TO 1120 if PSI AFTER 5 MIN. BLEED OFF PRESSURE IN IAAND WORKSTRING. 'OPEN ANNULAR. I TURN 15 TIMES TO RIGHTAND PICK UP, FREE. 5-5.5K TORQUE TO RELEASE FROM 116'30 - 00:00 7.50 RUNCOM P DECOMP R�ATCH LATCH UD 190 JOINTS OF 203 JOINTS 10/23/2019 00:00 - 01:00 1.00 RUNCOM i P DECOMP PULL LAST COUPLE JOINTS OF 4-1/2" TCII OUT. -BREAK OUT 4-1/2"TCII x 4-1/2"VAM TOP 1. X -OVER PUP —II kECOMP - LAY DOWN HALLIBURTON RATCH LATCH SEALASSEMBLY 101:00 - 05:30 4.50 RUNCOM P 1 PJSM, -CLEAN AND CLEAR RIG FLOOR IN 1 I PREPARATION FOR 9-5/8" CASING CUT. 11- INSPECTAND SERVICE TOP DRIVE, SWAP I ELEVATORS. .-5/CAMERON - CALL OUT TO ALL WEAR RING. INSTALLI3-5/8"WEARRING(8.75"ID) WEAR Printed 11/20/2019 12:37:34PM **All depths reported in Drillers Depths" North America - ALASKA - BP Page 7 of 11 Operation Summary Report Common Well Name: 11-07 AFE No Event Type: WORKOVER(WO) Start Date: 10/16/2019 End Date: 10/2612019 H-S4DW0019H9-EX-D1-WO-(2,144,872.00) Project: PBU _-- Site: 11 - - _ -- - Rig Name/No.: CDR -2 Spud Date/Time: 8/3/1992 12:00:OOAM Rig Release: 10/26/2019 Rig Contractor: NABORSALASKA DRILLING INC. BPUOI USA00001218 Active datum: KB @62.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) ! (usR) 05:30 - 06:00 2.50 RUNCOM P DECOMP PJSM FOR CUTTING 9-5/8". RIG UP CUTTER AND 2 JTS OF DRILL PIPE. CHECK OA, DEAD. CLOSE IN OA. RIH TO SPACE OUT CUTTING BLADES 20' BELOW 9-5/8" HANGER. START ROTATING 50 RPM THEN BRING PUMP UP SLOWLY, PUMP 5 BPM TURN 50 RPM, CUT 9-5/e". GOOD INDICATION OF CUT. 08:00 - 12:00 4.00 RUNCOM P DECOMP ,UD CUTTER BHA. PULL WEAR BUSHING. j RIG UP LRS. BACK OUT LDS ON 9-5/8" CASING. M/U SPEAR BHA TO TOP DRIVE. USE LRS TO PUMP 25 BELS 9.8#, 30 BELS DIESEL, THEN 25 BBLS 9.8#. -RIG DOWN LRS, FLOW CHECK OA, DEAD, OPEN BLINDS AND SPEAR 9-5/8" HANGER, BRING TO FLOOR. BREAK OUT SPEAR, UD CUT 9-5/8" UD SPEAR BHA. 12:00 - 17:00 1 5.00 RUNCOM P DECOMP BREAK XO OFF BOP TEST JOINT. RIG UP DOYON TONGS. CIRCULATE SOME MORE OUT TO TIGER �'. TANK, LOOKS LIKE SOME DIESEL IN STACK. ASSEMBLETONGS. BRING ELEVATORS AND HANDLING EQUIPMENT UP. RIG UP TORQUE TURN EQUIPMENT j 7.00 RUNCOM P 8,510.00 RUNCMP RUN 7" TIEBACK LINER - 17:00 00:00 - HOLD PJSM WITH CREWAND SERVICE IPERSONEL - PU AND RIH WITH FIRST JOINT OF 7" WITH WLEG - TEST FIT SAFETY VALVE AND CROSSOVER - GOOD - MAKEUP UPADDITIONALJOINTAND TNT j PACKER TO 11950 FT LBS WITH TORQUE TURN- BAKER LOC ALL CONNECTIONS BELOW TNT PACKER - RUN 7" 25# L-80 VAMTOP HC LINER WITH JET LUBE SEAL GUARD MAKE CONNECTIONS ---- -----.1 - ' TO 11950 FT LBS UTILIZING TORQUE TURN 10.00 _ RUNCOM P- 10/24/2019 !00:00 - 10:00 8,510.00 RUNCMP RUN 7" TIE BACK LINER "- HOLD PJSM WITH CREWAND SERVICE PERSONNEL - RUN 7" 25# L-80 VAMTOP HC LINER WITH JET LUBE SEAL GUARD MAKE CONNECTIONS TO 11950 FT LBS UTILIZING TORQUE TURN � I ' NOTE:HOLD DI KICK WHILE TRIPPING DRILL WITH JEFF WARD'S CREW WITH AAR, WELL SIMULATED SECURED IN 2 MINUTES 23 SECONDS. M/U FINAL JT OF 7". — UP Wi 268K, SLACKOFF 247K. - Printed 11/20/2019 12:37:34PM **All depths reported in Drillers Depths** North America - ALASKA- BP Page 6 of 11 Operation Summary Report Common Well Name'. 11-07 - - - - - - — - - - -- - -- - - - _- AFE No Event Type: WORKOVER(WO) Start Date'. 10/16/2019 End Date: 10/26/2019 H-S4DW0019H9-EX-Dl-WO-(2,144,872.00) Project: PBU Site: ii Rig Name/No.: CDR -2 Spud DaterFime: 8/3/1992 12:00:00AM Rig Release: 10/28/2019 Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00007218 Active datum: KB @62.00usft (above Mean Sea Level) Date From - To Hrs Task I Code NPT Total Depth I Phase Description of Operations _ (hr) (usft) 10:00 - 14:00 4.00 RUNCOM P 8,510.00 RUNCMP M/U LANDING JOINT AND HANGER. LAND HANGER AND BACK OUT LANDING JOINT. L/D LANDING JOINT. BRING CASING RACKOFF TO FLOOR, M/U JOINT OF OF. RIH WITH CASING PACKOFF AND SET. ! NOTE END OF 7" WLEG SETAT 8065- 114:00 - 16:00 2.00 RUNCOM P 8,510.00 RUNCMP MPSI, PRESSURE TEST CASING PACKOFF TO 3500 PASS. WSUP JOHN EGBEGEMBA REVIEWSAND 'APPROVES. RIG UP TO PUMP DOWN CATO PLACE CORROSION INHIBITORAND DIESEL IN 7"X --- 9,5/8" ANNULUS. _ 1600 - 18.45 2.75 RUNCOM P 8,510.00 RUNCMP PJSM WITH LRSAND RIG CREW FOR j PUMPING CORROSION INHIBITOR. PT LINES WITH LRS, GOOD. - CLOSE BLINDS, SET PUMP TRIPS AT 500 PSI. PUMP DOWNCATAKING RETURNS UP 7" AND OUT TO TIGER TANK, PUMP 150 BELS CORROSION INHIBITOR FOLLOWED BY 65 BBLS OF DIESELAT2.4 - BPM/310 PSI. SHUT IN OAAND R7 BLOW DOWN TIGER TANK LINE ! I VERIFY 0 PSI AND ZERO FLOW 4 '.OPEN BLINDS . NOTE: SLB SLICKLINE RIG UP WHILE PUMPING 1845 - 22:00 3.25 RUNCOM P 8,510.00 RUNCMP SLICKLINE OPERATIONS - HOLD PJSM WITH CREW WITH EMPHASIS ON WELL CONTROL. - MAKE UP SLICKLINE BHA#1 ( 5.85" DRIFT AND TUBING END LOCATOR WITH 3/16" 'SHEAR PIN I") - - RIH WITH SLICKLINE BHA#1 - LOCATE END OF 7" WLEG AT 8064' WLMD -PULLOUTOF HOLE MARKING SLICK LINEAT 8042 FOR SETTING WRP -LAY DOWN BHA All 22:00 - 00:00 2.00 RUNCOM P 8,510.00 RUNCMP SLICKLINE OPERATONS -HOLD PJSM WITH SLICKLINE AND RIG CREWS WITH EMPHASIS ON EXPLOSIVE HANDLING. ''.-MAKE UP SLICKLINE BHA #2 (7"WRP) -RIH WITH SLICKLINE BHA#2 -RIH TO 8042' WLMD AND START FIRING i. SEQUENCE. 10/25/2019 ,00:00 - 01:45 1 1.75 RUNCOM P 1 8,510.00 RUNCMP SLICKLINE OPERATONS -AT 8042' WLMD WITH WRPAND RUN .THROUGH FIRING SEQUENCE. -SET WRPAT 8042' WLMD -POOH WITH SETTING TOOL ON SLICKLINE RUN THROUGH DISARMING SEQUENCE AT 2000' j -LAY DOWN SETTING TOOLS AND LEAVE SLICKLINE RIGGED UP Printed 11/20/2019 12:37:34PM "All depths reported in Drillers Depths" North America - ALASKA - BP Page a of 11 Operation Summary Report Common Well Name: 11-07 - - - - - - - - - - - - - _ -- AFE No - Event Type: WORKOVER(WO) Start Date: 10/16/2019 .End Date: 10/26/2019 IH-S4DWO019H9-EX-Dl-WO-(2,144,872.00) Project: PBU — ---Site: 11 -- - Rig Name/No.: CDR -2 Spud Daterrime: 8/3/1992 12:00:OOAM Rig Release: 10/26/2019 Rig Contractor: NABORSALASKA DRILLING INC. BPUOI: USA00001218 Active datum: KB @62.00usft (above Mean Sea Level) - '— Date From - To 101:45 Hm Task Code NPT Total Depth Phase Description of Operations - 03:00 125 RUNCOM I P 8,510.00 RUNCMP SET/TEST 7- TNT -PACKER -HOLD PJSM WITH CREW -PURGE SURFACE LINES AND RIG UP TO TEST -LINE UP TO PUMP DOWN 7" SCAB LINER THROUGH KILL LINE TO A CLOSED CHOKE -BRING ON PUMP at 0.3 BPM AND BRING PRESSURE TO 3685 PSI IN 3.4 _ BBLS-OBSERVED PRESSURE STALLAT 2400 PSI INDICATING START OF PACKER SET. -PERFORM INTEGRITY TEST ON 7" SCAB 1 LINER- FIRST 15 MINUTES LOST 42 PSI, SECOND 15 MINUTES LOST 19 PSI - PASS -BLEED OFF PRESSURE -TOTAL FLUID I RETURNED 3.2 BELS .03:00 - 05:00 _ 2.00 RUNCOM P 8,510.00 - RUNCMP SLICKLINE OPERATIONS -HOLD PJSM WITH CREWS 1 j -MAKE UP WRP RETRIEVAL TOOLS --RIH ON SLICKLINE -LATCH ON TO WRP AND PULL FREE -POOH WITH WRP AND RETRIVALTOOLS LAY DOWN WRP AND SLICKLINE TOOL (STRING 05:00 - 07:00 __ 2.00 RUNCOM 1 P T— —�— "S -- 8,510.00 RUNCMP f PRESSURE TEST OA WITH LRS TO 1200 PSI. PASS AS PER 10-45 CRITERIA -LOSES 27 PSI FIRST 15 MINUTES, 4 PSI I I SECOND 15 MINUTES -SEND RESULTS TO WSUP JOHN ' EGBAGEMBAAND GETAPPROVALTO CONTINUE OPERATIONS 07:00 - 21:00 14.00 RUNCOM i P 1 8,510.00 RUNCMP PJSM WITH DOYON, HES AND RIG CREW FOR M/U 4-1/2" VAM TOP UPPER COMPLETION -PICK UP AND MAKE UP 4-1/2', L-80, 12.6 #, VAM TOP COMPLETION AS PER APPROVED TALLY -DRIFT 4-1/2" VAM TOP WHILE PICKING UP FROM PIPE SHED WITH 3.833" DRIFT -USE JET LUBE SEAL GUARD AND MAKE UP TO OPTIMUM TORQUE OF 4440 FT/ LBS WITH '.TORQUE -N -TURN -PUW= 110K, SOW= 106KAT 6200' MD -PUW=143K, SOW= 130KAT8371' MD -PICK UP JOINT 203 CHANGE OUT ELEVATORS AND MAKE UP CROSSOVER AND JOINT OF DRILL PIPE -MAKE UP TOP DRIVE MONITOR PIPE DISPLACEMENTAT TRIP TANK WITH PROPER DISPLACEMENT OBSERVED 21.00 - 23:00 2.00 RUNCOM P 8,510.00 j RUNCMP CIRCULATE -CIRCULATE WELLAT4 BPMAT320 PSI TO INCREASE LUBE CONCENTRATION TO 0.5% NXS LUBE AND 1.0% BARALUBE W-520 Printed 11/20/2019 12:37:34PM **All depths reported in Drillers Depths" Printed 11/20/2019 12:37:34PM **Ali depths reported in Drillers Depths" North America - ALASKA - BP Page 10 of 11 Operation Summary Report Common Well Name: 11-07 _ - - - --- - - - -- - -- AFE No — - �- - Event Type: WORKOVER(WO) Start Date. 10/16/2019 iEnd Data 10/26/2019 H-S4DW0019H9-EX-D1-WO-(2,144,872.00) Project: PBD Site: 11 _ Rig Name/No.: CDR -2 Spud Date/Time: 8/3/1992 12:00:00AM Rig Release: 10/26/2019 Rig Contractor: NABORSALASKA DRILLING INC. BPU01: USA00001218 _ Active datum: KB @62.00usft (above Mean Sea Level) _ Date From - To Hrs (hr) 1 Task Code NPT Total Depth (usft) Phase Description of Operations 23:00 - 00:00 1.00 I RUNCOM P 8,510.00 RUNCMP SPACE OUT -PUW=143K, SOW =134KAT 8371'MD -RIH -SET DOWN 10KAT 8388.97' MD AND THEN AN . ADDITIONAL 10K AT 8389.47 MD TO ENSURE HATCH LATCH IS ENGAGED -PICK UP 20K OVERPULL TO 8386.47- MDO VERIFY ENGAGEMENT SET DOWN TO NEUTRAL WEIGHT PLUS K ! DOWN AT 8388.37'MDAND MARK PIPE FOR SPACE OUT -LAY DOWN CROSSOVER AND JOINT OF DRILL PIPE _-02 10/2fi/2019 00:00 - 02:30 — 2.50 RUNCOM P 8,510.00 RUNCMP BLOW DOWN TOP DRIVE_ SPACE OUT -BLOW DOWN TOP DRIVE -CHANGE OUT ELEVATORS -LAY DOWN JOINTS 203 AND 202 MAKE UP PUPS -(9.81', 9.81', 7.81', 3.80') -MAKE UP JOINT 202 SWAP ELEVATORS MAKE UP TIW, PUMP IN SUB AND JOINTOF 02:30 - 06:00 3.50 RUNCOM P 8,510.007RUNCMP�PUMPCORROSION DRILL PIPE INHIBITORANO FREEZE PROTECT WELL J -HOLD PJSM WITH CREWS -RIG UP TO REVERSE CIRCULATE WITH RIG AND LITTLE RED SERVICES -LEAK TIGHT TEST LINES TO 3500 PSI -GOOD i TEST -LINE UP TO REVERSE CIRCULATE WITH RIG -PUMP 80° CORROSION INHIBITOR AT 4BPM j- AT 560 PSI -LINE UP LRS AND PUMP 75 BBLS 80" DIESEL 06:00 - 07:00 1.00 RUNCOM�' P 8,510.0000 RUNCMP DOWN IA TAKING RETURNS TO TIGER TANK___ U TUBE DIESEL -ISOLATE TIGER TANKAND LRS PUMP TRUCK -OPEN VALVE THAT CONNECTS TUBING TO IA _ IAND LET DIESEL UTUBE 0700 - 09:00 2.00 RUNCOM P 8,510.00 RUNCMP RIG DOWN HOSES AND LINES USED FOR CORROSION INHIBITOR AND FREEZE ,PROTECT -CONFIRM NO PRESSURE ON IAAND TUBING -ISOLATE IAAND TUBING -BLOW DOWN ALL LINES TO TIGER TANKAND BLOW DOWN CHOKE TRAILER �-REMOVE TIW, SIDE ENTRY SUBAND JOINT OF DRILL PIPE FROM RIG FLOOR ' -i -CHANGE E OUT ELEVATORS FROM DRILL PIPE II Ili TO TUBING ELEVATORS 'SWITCH POWER FROM HI -LINE TO RIG GENERATORS AT 0900 HRS -_ Printed 11/20/2019 12:37:34PM **Ali depths reported in Drillers Depths" North America -ALASKA - BP Page 11 of 11 Operation Summary Report Common Well Name: 11-07 - - _ - - - - - - -- - - - - - AFE No - -- Event Type. WORKOVER (WO) Start Date: 10/16/2019 End Date: 10/26/2019 H-S4DW0019H9-EX-D1-WO- (2,144,872.00 ) Project: PBU Site: 11 ' Rig Name/No.: CDR -2 Spud Date/Time: 8/3/1992 12:00:OOAM Rig Release: 10/26/2019 Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00001218 Active datum: KB @62.00usft (above Mean Sea Level) Date __ From - To His (hr) Task Code NPT Total Depth Phase Description of Operations 109:00 10:00 1.00 1 RUNCOM P 1 8,510.00 RUNCMPLA ND TUBINGSTRING -INSTALL TUBING HANGER AND LANDING JOINT -LAND TUBING STRING IN 9.8 PPG BRINE WITH 143K PUW AND 130K SOW -CONFIRM RATCH LATCH ENGAGED BY PICKING UP TO 155KAFTER LANDING TUBING (12K OVER) ! -RILDSAFTER WELLHEAD REP CONFIRM MARK ON PUP BELOW HANGER THROUGH IA -.._ VALVES 10:00 - 10:30 0.50 RUNCOM ! P 8,510.00 RUNCMP RIG UPFORMITOFTBGAND IA j 1 i -REMOVE LANDING JOINTAND LAY DOWN TO !! PIPESHED -PURGE STACKAND LINES FOR PRESSURE �— P TESTING -CLOSE BLIND RAMSAND CONFIRM LINE UP _ BY WALKING DOWN LINES 10:30 - 12:00 1.50 RUNCOM P 8,510.00 ! RUNCMP PRESSURE TEST TBG AND IA ! -PJSM AND REVIEW PRESSURE ! CROSSCHECK LIST -PERFORM MIT ON TUBING TO 3500 PSI -PRESSURE UP TO 3690 PSI WITH 68 PSI OBSERVED ON IA -PRESSURE STABILIZES AT 3500 PSI SO BUMP PRESSURE UP TO 3780 PSI -55 PSI LOSS DURING FIRST 15 MIN, 25 PSI LOSS DURING FINAL 15 MIN, 2 BBLS TO PSI UPAND 2 BBLS BLED BACK -CONFIRM NO PRESSURE AND OPEN BLIND RAMS ! -LINE UP AND PRESSURE IA UP TO 3290 I-90 PSI L 25 LOSS DURING FINAL 15 MIN, 3.2 BBLS TO PSI UP AND 3.2 BBLS BLED BACK � 1 i 'SEND CHART AND TESTING CRITERIA CALCULATORS TO WSUP FOR APPROVAL -OBTAIN APPROVAL TO PROCEED FROM 12:00 - 12:30 0.50 RUNCOM P ~ WSUP 8,510.00 RUNCMP BLOW DOWN AND RIG DOWN TESTING EQUIPMENT ! -BLOW DOWN ALL EQUIPMENTAND LINES TO T--- --r— L *12:30 13:30 1.00 P WHSUR 113:30 - 20:00 1 6.50 RIGID P P TIGER TANK ---00 j RU 8,510.00 RUNCMP ! INSTALLTWC WITH DRY ROD -PRESSURE TEST TWC FROM ABOVE TO 3500 PSI FOR 5 MIN. GOOD TEST _ 8,510.00 RUNCMP ! WORKTHROUGH RIG DOWN CHECKLIST -BLOW DOWN FLUID LINES -VAC OUT BOPS DOWN TO TUBING HANGER 1 -PREP BOP FOR NIPPLE DOWN -NIPPLE DOWN BOPS AND SECUIRE FOR TRANSPORT 'RELEASE RIGAT 2000 HOURS Printed 11/20/2019 12:37:34PM **All depths reported in Drillers Depths" ***SWCP 4517 ASSIST CDR2*** (cdr) DRIFTED TO END OF 7" LINER AT 8065' MD W/ 4.5" CENT, TEL, 7" RBP DRIFT RIH AND SET 7" BAKER RBP AT 8042' MD W/ E -FIRE. 10/24/2019 ***CONT ON 10/25/19 WSR*** ***SWCP 4517 ASSIST CDR2*** (cdr) PULLED 7" BAKER RBP FROM 8042' MD. 10/25/2019 ***JOB COMPLETED, RDMO*** T/I/O=TWC/0/0 Assisted FMC with installation of THA and Dryhole tree. Torqued to specs. Removed upper valve of dryhole and installed Baker Hughes upper tree.with Mach actuator. Torqued to API specs. FMC PT'd THA. R/U lubricator, PT'd through lubricator against TWC 300/low..5000/high 5 min. each... pass. see "Field Charted Tests" Pulled 4" CIW "H" TWC through tree. R/D lubricator, pt'd tree cap. R/D IA intagral flange & installed tapped blind flange. Torqued blind flange to 188 ft lbs. R/D OA intagral flange & installed tapped blind flange. Torqued blind flange to 638 fl lbs. P/T'd IA & OA Low 300psi, High 10/27/2019 2500psi. FWP's 0/0/0 see log for details. ***WELL S/I UPON ARRIVAL*** (rwo capital) PULLED B&R/RHC PLUG BODY FROM 8,442' SLM LRS PERFORMED PASSING STATE WITNESSED MIT -IA (state rep Lou Laubenstein), MIT -T, MIT -OA passed PULLED P -PRONG FROM PX -PLUG @ 8,637' SLM (rig trash in pulling tool) MADE 2 RUNS W/ 9'x 2.25" PUMP BAILER, MSFB FROM 8,643' SLM TO 8,644' SLM (1.25gal schmoo/rig trash) 11/4/2019 ***CONT WSR ON 11/5/19*** T/I/O= 0/5/-12 Temp= SI LRS unit 72 Assist Slickline(RWO CAPITAL), AOGCC witnessed (Lou Laubenstein) MIT -IA PASSED at 3216 psi (3000 psi Target pressure). Lost 23 psi in first 15 minutes and lost 4 psi in the second 15 minutes. Lost a total of 27 psi in the IA during 30 minute test. Pumped 3.4 bbls 45* Diesel to achieve test pressure. Bled back 3.1 bbls. MIT -T PASSED (2nd attempt) at 2671 psi (2500 psi Target pressure). Lost 22 psi in first 15 minutes and lost 15 psi in second 15 minutes. Lost a total of 37 psi in TBG during 30 minute test. Pumped 3.7 bbls of 45* Diesel to achieve test pressure. Bled back 2.4 bbls. MIT -OA PASSED at 1153 psi (1000 psi Target pressure). Lost 16 psi in the first 15 minutes and lost 7 psi in the second 15 minutes. Lost a total of 23 psi in OA during 30 minute test. 11/4/2019 Pumped 2.54 bbls of 45* Diesel to achieve test pressure. Bled back 2.1 bbls. ***CONT WSR FROM 11/4/19*** (rwo capital) RAN 9'x 2.25" PUMP BAILER, SNORKEL BOTTOM TO PX -PLUG BODY @ 8,644' SLM (recovered 3 small pieces of metal) PULLED 4 1/2" PX -PLUG BODY FROM 8,642' MD 11/5/2019 ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** T/1/0=310/VAC/10. Temp = SI. Assist Ops w/ POI. IA FL @ near surface. OAP @ surface. Well POI @ 20:30 hrs. Bled a total of 2.3 bbls of fluid from IA & 1.2 bbls from OA Currently bleeding IAP & OAP as needed while well stabilizes. 11/6/2019 Cont on WSR 11/7/19 Cont from WSR 11/6/19. Assist Ops w/ POI. Bled IAP & OAP multiple times due to thermal expansion, returned a total of 2 bbls total. IAP BUR around 50 psi an hour. Final WHPs = 1250/66/vac. 11/7/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. T/I/O = 1210/900/200. Temp = 1310. WHPs (post POP). TP decreased 40 psi, IAP increased 834 psi, OAP increased 200 psi from 11/7/19. 11/9/2019 ISV = C. WV, SSV, MV = O. IA, OA = OTG. 16:45. Daily Report of Well Operations PBU 11-07 TWO = 1240/920/220. Temp = 130°. Bleed IAP & OAP (post POI). On PWI. IA & OA FLs @ surface. Bled IAP to BT from 920 psi to 200 psi in 11 min (0.59 bbls), OAP decreased to 140 psi. Bled OAP to BT from 140 psi to 20 psi in 4 min (0.27 bbls), IAP decreased to 190 psi. Monitored for 30 min. IAP increased 50 psi and OAP increased 20 psi. Bled IAP from 240 psi to 150 psi, OAP decreased to 30 psi. Monitored for 30 min. IAP increased 50 psi and OAP increased 10 psi. Final WHPs = 1240/200/40. 11/9/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 23:00 TWO = 1260/950/140. Temp = 1300. Bleed IAP to 50 psi & Monitor (Eval IA Repressurization). On PWI. IA FL @ surface. Bled IAP to BT from 950 psi to 50 psi in 2 min (0.70 bbls). Monitor and bleed IAP as needed. IAP increased 420 psi and OAP 11/10/2019 increased 90 psi in 3.5 hrs. ***WSR continued from 11/10/19*** TWO = 1260/470/130. Temp = 1300. Bleed IAP to 50 psi & Monitor (Eval IA Repressurization). IA FL @ surface. Continue monitoring IAP BUR post bleed. IAP increased from 50 psi to 580 psi in 5 hrs, bled IAP from 580 psi to 50 psi (0.29 bbls, 0.99 bbls total). Monitored an additional 4 hrs (9 hrs total). IAP increased 260 psi in 4 hrs. Final 11/11/2019 WHPs=1260/310/100. T/I/O = 1590/1000/180. Temp = 1300. Bleed IAP to 300 psi (UIC). IA FL @ surface. Bled IAP from 1000 psi to 20 psi in <5 mins (1 bbl). During bleed OAP decreased 110 psi. Monitored for 30 minutes. IAP increased 70 psi & OAP increased 10 psi. Final WHPs = 11/11/2019 1590/90/80. T/1/0=1390/1050/210. Temp = 1300. AOGCC MIT-IA PASSED to 2708 psi. (Regulatory Compliance). On PWI. AOGCC witnessed by Jeff Jones. Max pressure = 2750 psi. Target pressure= 2500 psi. IA FL @ surface. Used 1 bbl diesel to pressure IAP to 2749 psi. IAP lost 38 psi in first 15 minutes &3 psi in second 15 minutes. Total loss = 41 psi. Bled IAP from 2708 psi to 310 psi (2 bbls). Monitor. for 1 hr. IA increased 150 psi in 1 hr. Final WHPs = 1390/460/160. 11/16/2019 ISV = C. WV, SSV, MV = O. IA, OA = OTG. 12:00 TREE = My WELLHEAD = FMC ACTUATOR= BAKER KB. ELEV = 62' BF. ELEV = 29' KOP = 3900' Max Angle = Da 32'@ 6400' Da I ODrVSaz 7 SAFETY NOTES: WELL REQUIRES A SSSV 11-0 / WHEN ON ML=•* 87' GAP FROM W LEL@8663' 95re^ rbc srue 5' TO PKR @ 8750'. TBG TAIL PARTED DURING 04108RW0 SEE FISM... E UCTORtunMD=9343'0,tunTVD= 880'S 4" 13-wcsG,72#,L-0OBTC,ID=12.347' 265W Minimum ID = 3.866" @ 8416' 7" X 4-1/2" HES TNT PKR 3- CSG, L-80 LTC XO TO S0095 LTC BTRS —F 752V 7" CSG, 26#, LA0 VAM TOP HC, ID = 6276" 8070' TOP OF 7" LNR 8092' 14 -112 -13 -CR RATCH LATCH ASSY, ID = 3.919" 838W 4-12" TBG,12.6#, LA0 VAM TOP, h 8516' .0152 bpf, D = 3.958' 4-12"TBGSTUB 8516' 9-5/8' CSG, 47#, S0095 LTC BTRS, D = 8.681' I 4-12' 14-12" HES X NIP, ID = 3.813" 195/8" X 7" HES TNT PKR. D = 5.900" 8070' 8092' 9-518"X 7"LTP w/LNR HGR&TIEBACK SLV, D = 6.313" 9-518' MLLOUT WINDOW (11-07ST) 8287'-8334- 3362' 287'-8334' 3362' 4-12" HES X NIP, ID = 3.813" 813- 1 8664' 1 D = 3.958' 4-12' TBG, 12.6#, L-80 TDS, I 877V .0152 bpf, D = 3.958" I PSTD I 7-X 4-12' HES TNT PKK ID = 3.856" 4-12" HES X NIP, ID = 3.813" 7' LNR, 26#, LA0 NSCC, .0383 bpf, ID =6.276- 9472' DATE PERFORATION SUMMARY COMMENTS DATE REV BY GOMMENIS 02/20182 REF LOG: BHCS ON 08/0652 ORIGINAL COMPLETION 1120/19 JNJJMD ADPERFS 08109192 ANGLE AT TOP PERF: 19° @ 9150' Note: Refer to Production DB for Hsborical rfdata SIZE SPF INTERVAL I ODrVSaz I DATE 2-75' 6 9150 - 9175 O 09/09/19 2-7/8' 6 9205-9225 O 09/08M9 3-15' 4 9296-9312 O 082152 9-5/8' CSG, 47#, S0095 LTC BTRS, D = 8.681' I 4-12' 14-12" HES X NIP, ID = 3.813" 195/8" X 7" HES TNT PKR. D = 5.900" 8070' 8092' 9-518"X 7"LTP w/LNR HGR&TIEBACK SLV, D = 6.313" 9-518' MLLOUT WINDOW (11-07ST) 8287'-8334- 3362' 287'-8334' 3362' 4-12" HES X NIP, ID = 3.813" 813- 1 8664' 1 D = 3.958' 4-12' TBG, 12.6#, L-80 TDS, I 877V .0152 bpf, D = 3.958" I PSTD I 7-X 4-12' HES TNT PKK ID = 3.856" 4-12" HES X NIP, ID = 3.813" 7' LNR, 26#, LA0 NSCC, .0383 bpf, ID =6.276- 9472' DATE REV BY COMMENTS DATE REV BY GOMMENIS 02/20182 R36 ORIGINAL COMPLETION 1120/19 JNJJMD ADPERFS 08109192 N2ES SIDETRACK (11-07ST) 04/17108 N4E5 RWO 1026119 N-COR2 RWO 11/11/19 JMD DRLG HO CORRECTIONS 11/13/19 TH/JMD FINAL ODE APPROVAL X 4-12' BOWEN CSG PATCH -12'HES X NF, D=3.813' TX4-1/2'BKR S-3 PKR,D=3.870" 4-12'WLEG, ID =3.958' 8750' P7 RX Z D = HBBP 3.960' 1 9215' 1 = 3.958' FISH - TBG w /NFS & V PRUDHOE BAY UNIT WELL: 11-07 PERMfT No: 91811770 API No: 50-029-20687-00 SEC 33, T11 N, R1 5E. 253 FNL & 81 FEL BP Exploration (Alaska) MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Lou Laubenstein Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, November 13, 2019 SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. 11-07 PRUDHOE BAY UNIT 11-07 Sre: Inspector Reviewed By: P.I. Supry A [� NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 11-07 API Well Number 50-029-20687-00-00 Inspector Name: Lou Laubenstein Permit Number: 181-177-0 Inspection Date: 11/5/2019 Insp Num: mitLOLI91105104832 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 11-07 'Type Inj N TVD 8137 Tubing z o ` o - 0 - PTD 1 1811 70 Type Test SPT Test psi 3000 IA 1 2021 3243 3220 3216 - BBL Pumped: BBL Returned: OA 58 53 - 51 - Interval IOTI ER I P/F P Notes: MIT -IA pre Injection test, per Sundry 319-377 Wednesday, November 13, 2019 Page 1 of I Wallace, Chris D From: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Wednesday, November 6, 2019 10:16 AM To: AK, OPS EOC Specialists; AK, OPS FS2 DS Ops Lead; Ak, OPS FS2 Facility PTL; Ak, OPS FS2 Field PTL; AK, OPS FS2 OSM; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Alatalo, Travis; G GPB FS2 Drillsites; Rupert, C. Ryan; Wallace, Chris D (CED) Cc: Varble, Doug A; Regg, James B (CED); AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity, AK, GWO SUPT Well Integrity, AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User, Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Obrigewitch, Beau; Smith, Travis T (CONOCOPHILLIPS); Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J Subject: OPERABLE: Injector 11-07 (PTD #1811770) passed MIT -IA post RWO All, Injector 11-07 (PTD #1811770) was made Not Operable on 03/02/19 after it failed a state witnessed MIT -IA. The well was recently worked over and the production tubing was replaced. On 11/04/19, with the well offline, Fullbore performed a passing State witnessed MIT -IA to 3,216 psi. The passing MIT -IA confirms two competent barriers to formation and will now be classified as OPERABLE. After the well is put on injection and thermally stable, another AOGCC witnessed MIT -IA will be performed. Please note the fluid packed annulus when putting the well on injection. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization -Alaska Office: 907-659-8110 From: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Saturday, March 2, 2019 11:06 AM To: AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS FS2 DS Ops Lead <AKOPSFS2DSOpsLead@bp.com>; Ak, OPS FS2 Facility PTL <AKOPSF52FacilityPTL@bp.com>; Ak, OPS FS2 Field PTL <AKOPSFS2Field PTL@bp.com>; AK, OPS FS2 OSM <AKOPSFS20SM1@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Alatalo, Travis <Travis.Alatalo@bp.com>; G GPB F52 Drillsites <ggpbfs2drillsites@BP.com>; Rupert, C. Ryan <Ryan.Rupert@BP.com>; Smith, Travis T (CONOCOPHILLIPS) <travis.smithl@bp.com>; 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> Cc:'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWelllntegri@bp.com>; AK, GWO Projects Well Integrity<AKDCProjectsWelllntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellintegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dem pseyl@bp. com>; Dickerman, Eric <Eric.Dickerman@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.iVlontgomery@bp.com>; Munk, Corey <Corey.Munk@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; O'connor, Katherine <Katherine.O'connor@bp.com>; Sternicki, Oliver R THE STATE Alaska Oil and Gas OfALASKA Conservation Commission 333 West Seventh Avenue GOVERNOR MIKE DUNLEAVY Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogc c. al a s ka.gov Sean Mclaughlin Engineering Team Lead BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 11-07 Permit to Drill Number: 181-177 Sundry Number: 319-377 Dear Mr. Mclaughlin: Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, lzgr� Daniel T. Seamount, Jr. Commissioner DATED this �day of August, 2019. ABDMS�'�Auc 3 0 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 - 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0 Operations shutdown ❑ Suspend ❑ Perforate 0 • Other Stimulate ❑ Pull Tubing H Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Curren Well Class: Exploratory ❑ Development ❑ 5. Permit to Drill Number: 181-177 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigrephic ❑ Service 0 6, API Number: 50-029-20687-00-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 PBU 11-07 9. Property Designation (Lease Number): 10. Field/Pools. ADL 028325 PRUDHOE BAY, PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (8): Total Depth TVD(ft) : Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD). Junk (MD): 9472 - 8986 8642 8199 2620 8642 8270 Casing Length Size MD TVD Buret Collapse Structural Conductor 80 20" 32-112 32-112 1490 470 Surface 2627 13-3/8" 32-2659 32-2659 5380 2670 Intermediate 8257 9-5/8" 30-828730-7861 6870 / 8150 4760/5080 Production Liner 1380 7" 8092-9472 1 7680-8986 1 7240 1 5410 Perforation Depth MD (f): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9296-9312 8820 - 8835 4-1/2" 12.6# L-80 28 - 8674 / 8751 - 8771 Packers and SSSV Type: 4-1/2" Baker S-3 Packer Packers and SSSV MD (ff) and TVD (R). 8586 / 8146 41/2" TIW HBBP Packer 8751 18303 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development ❑ Service 0. 14. Estimated Date for Commencing Operations: August 28, 2019 - 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG 0 ' GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Hyatt, Trevor be deviated from without prior written approval. Contact Email: Trevor. HyattQbp.00m Authorized Name: Mclaughlin, Sean M Contact Phone: +1 907 564 4627 Authorized Title, Eng eering Team Lead - CTD Authorized Signature: j Date: Wit /1 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: L✓_ (� Plug Integrity ❑ BOP est W' Mechanical Integrity Test N� Location Clearance ❑ Other: IV0�6e �.9 / TO—VKW�61 BDMSLfCA-'AUG 3 01019 Post Initial Injection MIT Req'tl? Yes El No ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: 16 -210 y APPROVED BYTHE �'/ J Approved by: COMMISSIONER COMMISSION Date: Q 2�{/ I 9�ZyPvi(('� ORIGINAL //%�� " � ze-Attop Submit Form and Form 10403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt RWO/CTD Engineer Obp Date: August 14, 2019 Re: 11-07 Sundry Approval Well Type: Injector Current Status: The well is currently listed as non-operable (IAxOA communication). Request: Sundry approval is requested for plans to restore production casing integrity. History and current status: Well 11-07 was drilled in Jan 1982 as a producer and converted to injection in 1984. It was then sidetracked in August 1992. The old well name was changed to 11-07PB1 in the database and the new sidetracked well was called 11-07. The well has been injecting both seawater and produced water since 1984. In May 2006, the well developed TxIA communication and failed integrity testing. This led to a RWO in 2008 when the tubing was swapped. There was a history of slight IAxOA in this well prior to the RWO but it was not i addressed. Most recently the well failed an AOGCC witnessed MIT -IA on 3/2/19 and was made not operable. A subsequent LDL on 3/30/19 did not produce any results and failed to establish a leak rate when IA was pressurized. It is possible that the leak sealed up with temperature fluctuations. The well is planned to be POI under eval and a second LDL will be ran while the well is at operating temperature. It is currently shut-in with a TTP set. �'as r Proposed Plan: The Nabors CDR2 Rig will cut and pull the top section of 9-5/8" production t g. A 7" casing tieback will be ran inside the 9-5/8" to just above the T' liner to restore PC integrity. ASP=2620 psi. Note: Prior to the casing repair it is planned to perforate within the same pool to ensure injectivity. CDR2 Workover BOP stack will be configured as follows (BOP schematic attached for reference): • One Annular preventer • One Blind Ram -type preventer • Mud cross with outlets for choke and kill lines One Ram -type preventer dressed with Ram or VBR depending on what pipe is being ran/pulled. Testing will be in accordance with State and BP policy of a 7 day BOP test. Testing will be 3500 psi high and 250 psi low for all components. The following describes work planned and is submitted as an attachment to Form 10403. A schematic diagram of both the current and proposed wellbore is attached for reference. Scope of Work: The primary objective of this Aa- is to perform a casing repair to restore IA x OA integrity. Pre -Ria (—Auaust 25th. 2019): /"/��fa-sS .V G IV /%7,4 y //— 2049 osr a ii, it 1. W - PPPOT -T and IA. Function LDS. 2. F - MIT -OA. MIT -IA. MIT- IAxOA (if needed) 3. EL - Perforate. 9/sla'- 9/0,Pr VZZS' 4. SL - Set PX Plug / 5. EL - RCT Cut Tubing. 6. F- Circ well. MIT TxlAx A. Fire AlAj�w98� 7. V - Set BPV. Pre 9T-6 Tree Work..9er CJ, /Y/ /T fv 2o00Ps/ Proposed RWO Procedure October 151,2019 : 1. MIRU.TestBOPE. D �fp< p 3Sao�5/ zN�. hef,G� 2. Pull L-80 Tbg. 3. Cut and pull 9-5/8". —1 ry r 4. Run T' tieback/Scab liner. Set packerK est. ^ 7'/�,q -r� �� t'/,/•NG /JU 4'M S�7Ol 5. Run 4-1/2" L-80 Tbg. 6. Freeze protect and DR MO. e,A // f 7-&_9 TES i �A�'JD Post ria Work: �-- `r 1. F: Circ inhibited SW, Drop B&R, Set and test packer. MIT -T & MIT -IA. 2. S: Pull B&R, RHC sleeve. Fish PX plug. 3. V: Tree work as necessary. Install S -Riser / 4. F: State witness of MIT IA test prior to injection. % E57 ' 1`0 30aO�Si — Z YAr e7 a0`� e' e 5. POI 6. F: State witness of MIT IA test while on injection. Trevor Hyatt CC: Well File RWO/CTD Engineer 564-4627 Joe Lastufka Rixse, Melvin G (CED) From: Hyatt, Trevor <Trevor.Hyatt@bp.com> Sent: Tuesday, August 20, 2019 3:04 PM To: Rixse, Melvin G (CED) Cc: Hyatt, Trevor Subject: RE: PTD181-177, Sundry Request 319-377, RWO Questions, PBU 11-07 Mel, Please see the below answers to your questions, let me know if you need anything else. 1. Step #3, where and what will be perforated? • Adperfat 9150' — 9175' MD (24P) • Adperfat 9205' — 9225' MD (22P) 2. Step #5, is the —depth of tubing cut 8,505' MD? • Yes that is the plan. 3. Step #6, Will this be a KWF? When pulling tubing and 9-5/8" casing what is the 2"d independent barrier to the PXP plug with an open 9-5/8" x 13-3/8" shoe? • We will be using 9.8 ppg brine, this will be KWF. Also, we have a passing OA test 4/2/2008 to 2000 psi. Plan is to test this again pre -rig to verify that we have a closed 9-5/8" x 13-3/8" shoe. 4. Step #6, Will there be a IC test above the lower packer? AOGCC regs require casing integrity at the confining zones for injectors. This should be assured with a test or a variance request to describe that confining zones will be above the new packer if casing is not tested at the existing packer. We have a passing MIT -IA test on 4/11/2019 to 2500 psi. We will be doing an IA test pre rig that will test the 4-1/2" x 7" packer. We will also do an IA test to test the new 4-1/2" x 7" packer after the new completion is set. Maybe I'm not fully understanding the question, so let me know if you need more info? S. Step #7, What CTD work will be done? This is a RWO. • No CTD work will be done. Just means to set up the tree for the CDR2 rig to move over. 6. RWO Step #1, What will BOPE be tested to? What size rams? • 250 psi low and 3500 psi high • Bottom rams will have 4-1/2" x 7" (for the tubing and the 7" casing) 7. RWO Step #3, What size rams? Any spool change for hanging 7"? (1 believe we should have a wellhead drawing or a written description how this will be done.) • Bottom rams will have 4-1/2" x 7" (for the tubing and the 7" casing) • We plan to cut the top —60' of 9-5/8" and pull it in one pick, above the BOP. • Plan to cross the 7" over to 9-5/8" at surface to set in casing spool 8. RWO Step #4, What size rams? • Bottom rams will have 4-1/2" x 7" (for the tubing and the 7" casing) 9. RWO Step #5, What size rams? 0 Bottom rams will have 4-1/2" x 7" (for the tubing and the 7" casing) 30. Post Rig Step #4, What pressure will you test IA to? • 250 psi low and 3000 psi high Trevor Hyatt BP Exploration (Alaska) GWO — Drilling Engineer Coil Tubing Drilling & Rig Workover Trevor. Hyatt Otip.com Cell: 907-223-3087 From: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Sent: Friday, August 16, 2019 11:21 AM To: Hyatt, Trevor <Trevor.Hyatt@bp.com> Subject: PTD181-177, Sundry Request 319-377, RWO Questions, PBU 11-07 Trevor, AOGCC has the following questions regarding Sundry Request 319-377 for a RWO on PBU 11-07: 1. Step #3, where and what will be perforated? 2. Step #5, is the - depth of tubing cut 8,505' MD? 3. Step #6, Will this be a KWF? When pulling tubing and 9-5/8" casing what is the 2nd independent barrier to the PXP plug with an open 9-5/8" x 13-3/8" shoe? 4. Step #6, Will there be a IC test above the lower packer? AOGCC regs require casing integrity at the confining zones for injectors. This should be assured with a test or a variance request to describe that confining zones will be above the new packer if casing is not tested at the existing packer. 5. Step #7, What CTD work will be done? This is a RWO. 6. RWO Step #1, What will BOPE be tested to? What size rams? 7. RWO Step #3, What size rams? Any spool change for hanging 7"? (1 believe we should have a wellhead drawing or a written description how this will be done.) 8. RWO Step #4, What size rams? 9. RWO Step #5, What size rams? 10. Post Rig Step #4, What pressure will you test IA to? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska zov). TREE = CNV WELLHEAD= FMC ACTUATOR= BAKERC KB. ELEV = 67 BF. ELEV = 29' KOP = 3900' Max An = 32° 6400'gle Dahxn MD = 9343' Dabm TVD = 8600 -- 11-0 7 20' #, HAO, TO71—�TTI 91.5#, H40, D =19.124' 13-3/8' CSG, 7211, L-80 BTC, D =12.347' I—L 260 Minimum ID = 3.813" @ 2107' 4-1/2" HES X NIPPLE 1 9 -WB- CSG, L-80 LTC XO TO S0095 LTC BTRS TOP OF 7- LNR PERFORATION SUNMARY REF LOG_ BFICS ON 08/06/92 ANGLE AT TOP PERF_ 14° @ 9296' We: Refer to Production DB for historical perf data CSG, 47#, S0095 LTC BTRS, D = 8.681' 4-1/2' TBG, 12.6#, L-80 TCI, .0152 bpf, D = 3.958' 4-12' TBG, 12.B#, L- .0152 bpf. D = 3.958' SAFETY NOTES: WELL REQUIRES A SSS - V ---WHEN ON ML ••• 87' GAP FROM W LEG @ 8663' TO PKR @ 8750'. TBG TAIL PARTED @ 8771' DURING 04/08RW0 SEE FIS -- 14-1/2- HES X NP, ID = 3.813" allWZ 7- BKR TEBACK SLV, D = 7.50' 8100' 9 -SB' X 7' BKR LTP, D = 6.313' 6104' 9-5/8' X 7- LNR HGR D = 6.313- 9-5/8- MLLOUT WNDOW (11-07ST) 8287' - 8334' 8666' I 4-1/2' HESS X NP, D = 3.813' 1 8664° 1 1 8771' 1 7- LNR, 26#, L-00 NSCC, .0383 bpf, D = 6.276' 9472' DATE REV BY COMMENTS 11 DATE REV BY COMMENTS 02/2082 R35 ORKMALCONF ETM 11/17/08 ?/PJC DRLGDRAFTCORRECTIONSS 08AW WES SDEMWK 11-075 11/18819 GMD/PJC DRLGDRAFTCORRECTDNS 8411788 ROES RWO 02/14/11 MB/JMD ADDED SSSV SAFETY N07E 0504JW JNA/PJC FISH -TT BTM (4/17)08 RVVO) 04/01/19 MWJMD SETPXPLUG(03lJ7719) 0529108 RCIPJC CORRECTIONS 0621/19 RB/JMD PULLED PX PLUG 5J79 OWSM RC/PJC DRLGCORRECTIONSS 08/15/79 JNL/JMD ADDED BF ELEV 8 EDITED CON 7- X 4-1/2' BKR S-3 PKR, D = 3.870' J� 4-72' HES X NP, D = 3.813' vv�cv, u= s.aso- 7' X 4-1/2' TNV HBBP PERM PKR, D = 3.960' 4-1/2' PART® Tr, D = 3.958' PRUDHOE BAY UNIT VVELL 11-07ST PERMIT No: 1811770 API No: 50-029-20687-00 BP Exploration (Alaska) TBG TAIL i8 MEG TfiEF= aW WE LWEAD= FMC ACTUATOR= BAKER KB. EXV = 67 BF. AEI/ - 7 KOP= 3900' Max Arg@ = 32'@ 6400' Datum MD= 9343' Oat= TVD= Sam, SS 11-07 SAFETY NOTES: WE—LL REQUIRES A SSSV PROPOSED WHEN ON ML "' 87' GAP FROM WLEG @ 8663' PW 0 TO PKR @ 8760'. TBG TAIL PARTED @ 8771' DURING 04108 RWO(SEE RS OONJU.TOR 4, 1-40, 19.124' 13318' CSG, 72#, L-80 BTC, D= 12.34r H Minimum ID = 3.813" @ 2107' 4412" HES X NIPPLE 'CSO, L-80 LTC XO TO 50095 LTC BTRS ITOPOF7- LNT I 7"x4-1/2"HES TNT PP 4-1/2"HES XNIP Above and Bebw Packer 711x4-1/Z"UM Overshot 4-1/2" 12 b# L -8O, Vam Top Tubitg Tub:hg Stub @ 8505'M D REF LOG: BRCS ON 08N6/92 ANGLE AT TOP PERF: 14' @ 9296' Refer to Production DB for historical o BLriL1l 0313 Ki, 12.8#, L-80 TCF, ', D=3.958' 4-12• TBG, 12.6#, L- 0152 6pf, D= 3.958' 7" Ltd DATE REV BY 11/17/08 W PJC 0 2100' —14-12' HM XNP, D= 3.813" 9578"Stub@ 100' 9-5//8"x 7"L-80 HES PP 7"26# L-�B 0, Vam Top C asng 711W LEG @ -8000'M D 8100' -{9-5/6' X r BKR LTP, D=6.313' 8104' 9-5/8' X r LN2 FIGR, D=6.313 9-518' 1M -LOUT WIDOW (11-07ST) 8287' - 8334- 86W - 4-12" FES X NP, IO = 3.813" 867T 1-7-X4-12'SKR S-3 FKR D=3.870' 864 -114-12'N'.SXNP,D-3.813' a642' �� 4-vr Px I=LUG fo3u3v19> 4-12' VN_EO, D= 3.958' T X 4-12' TNV FBBP FEW" D=3.960' 412' PARF®TT, 17' MARKER JOINT I H D = 6.276' PRUDHOE BAY LI IF 1 ETMF OT'15_� W 11-0757 IONS , PIND No: 7811770 NOTE AS No: 50-029-2D687-00 SEC 33, TI 1N. 1115E 253 FFL 8 81 Flu BP 6cploralion (Alaska) TBG TAIL II iBVNEG 12' HYDRIL 13-5/8° 5K PS GK ANNULAR BOP LATCHED HEAD 5K FLANGE CONNECTION 3-118" 5,000/ WP CAMERON TYPE F" GATE VALVE HYDRIL 13-5/8" 5k PSI MPL SINGLE GATE 3-1/8" 5,OOO1 WP FLANGED CONNECTION CAMERON HCR VALVE DRILLING SPOOL 1/16" KILL LINE 13-5/8"-5K PSI FLANGED 3"-5K PSI FLANGED OUTLETS HYDRIL 13-5/8" Sk PSI MPL SINGLE GATE FLANGED CONNECTION Wallace, Chris D (CED) From: Wallace, Chris D (CED) Sent: Wednesday, July 17, 2019 7:30 AM To: AK, GWO Well Integrity Engineer Cc: Regg, James B (CED); AK, GWO Well Integrity Well Information Subject: RE: Permission to put Injector 11-07 (PTD #1811770) online for diagnostics Andrew, Your plan as below is approved. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West T^ Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276- 7542 (fax), chrismallace@alaska.¢ov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.aov. From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday, July 16, 2019 2:41 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; AK, GWO Well Integrity Well Information <akgwowel lintegritywe @ bp.com> Subject: Permission to put Injector 11-07 (PTD #1811770) online for diagnostics Mr. Wallace, Injector 11-07 (PTD # 1811770) was made Not Operable and shut in on 03/02/19 after it failed an AOGCC witnessed MIT -IA. The well operates under AIO 4G.004 for water only injection with a known IAxOA communication. On 03/31/19 a LDL was performed, but no leaks could be identified nor could the IAxOA communication be replicated. On 04/11/19 a diagnostic MIT -IA was performed with the well shut-in and passed to 2,465 psi. BP is requesting your permission to put the well Under Evaluation and place on injection with the intent of activating the leak and performing another LDL. Plan forward: 1. Ops: Put on PWI 2. DHD: Perform MIT -IA, establish LLR 3. Slickline: Perform LDL 4. Well Integrity Engineer: Additional diagnostics as needed Please respond at your earliest convenience. Andrew Ogg Well Integrity Engineer BP Global Wells Organization - Alaska Office: 907-659-8110 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg,, 1I f 2'tci DATE: Tuesday, April 9, 2019 SUBJECT: Mechanical Integrity Tests P.1. Supervisor ' ` /`1 1 ' BP EXPLORATION (ALASKA) INC. 11-07 FROM: Bob Noble PRUDHOE BAY UNIT 11-07 Petroleum Inspector Ste: Inspector Reviewed By: P.I. Supry —1 NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 11-07 lnsp Num: MARCN190302112317 Rel Insp Num: API Well Number 50-029-20687-00-00 Inspector Name: Bob Noble Permit Number: 181-177-0 Inspection Date: 3/019 Packer Depth Pretest Initial I5 Min 30 Min 45 Min 60 Min Well 11-07 IType lnj w -TVD 8137 "Tubing a'7 16'7 oz7 PTD 1811770 Type Test SPT Test psi 2034 IA 433 z7ooz5o7 BBL Pumped: 13=BBL BBL Returned: 4.5 OA 513 826 1172 - Interval REQVAR IP/F F T Notes: AA 4G.004 requires MIT -IA to max injection pressure (1850). 2700 psi was used for a test pressure. At the 15 min reading a rapid increase was rl inin the OA pressure. So IA was bled off because of 1A to OA comm. Tuesday, April 9, 2019 Page 1 of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg7 �I 11 DATE: Thursday, Much 7, 2019 SUBJECT: Mechanical Integrity Tests P.I. Supervisor `�j I l� BP EXPLORATION (ALASKA) INC. 11-07 FROM: Bob Noble PRUDHOE BAY UNIT 11.07 Petroleum Inspector Ste: Inspector Reviewed By: P.I. SuprvS�e— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 11-07 Insp Num: mitRCN190302112317 Rel Insp Num: API Well Number 50-029-20687-00-00 Inspector Name: Bob Noble Permit Number: 181-177-0 Inspection Date: 3/2/2019 ' Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1 11-07 Type Inj w "TVD s137 "Tubing 1627 na 1627 L_ PTD su77o -type Test sPT Test psi 2014 Ip -1 2700 07 BBL Pumped: - 43 BBL Returned: 4.z OA 3 ^o 117, Interval REQvAR �P/F { E Notes- AA 4G.004 requires MIT -IA to max injection pressure (1850). 2700 psi was used for a test pressure. At the 15 min reading a rapid increase was noted in the OA pressure. So IA was bled off because of IA to OA comm. Thursday, March 7, 2019 Page 1 of 1 Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Saturday, March 2, 2019 11:06 AM To: AK, OPS EOC Specialists; AK, OPS F52 DS Ops Lead; Ak, OPS FS2 Facility PTL; Ak, OPS FS2 Field PTL; AK, OPS FS2 OSM; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Alatalo, Travis; G GPB FS2 Drillsites; Rupert, C. Ryan; Smith, Travis T (CONOCOPHILLIPS); Wallace, Chris D (DOA) Cc: Regg, James B (DOA); AK, GWO Completions Well Integrity, AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey, Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J Subject: NOT OPERABLE: Injector 11-07 (PTD #1811770) failed AOGCC witnessed MIT -IA All, Injector 11-07 (PTD #1811770) failed an AOGCC witnessed MIT -IA today. The well is now classified as NOT OPERABLE. Please shut in and freeze protect at the earliest convenience. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization - Alaska Office: 907-659-8110 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday,April 21,2017 TO: Jim Regg1(j 7 P.I.Supervisor �l SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. 11-07 FROM: Chuck Scheve PRUDHOE BAY UNIT 11-07 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv, .-- 1 NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 11-07 API Well Number 50-029-20687-00-00 Inspector Name: Chuck Scheve Permit Number: 181-177-0 Inspection Date: 2/21/2017 Insp Num: mitCS170221145926 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 11-07 , Type Inj W'TVD 8137 ' Tubing 970 969 ' 965 963 968 - PTD 1811770 - Type Test SPT Test psi 2034 . IA 288 2491 . 2428 - 2380 - 2324 - BBL Pumped: BBL Returned: OA 285 561 - 645 , 1 725 - 832 Interval REQVAR P/F F Notes: Tested per AIO 4G.004. Well showed obvious IA x OA communication. DHD lost track of bbls pumped and bbls returned. „ gG 1 520 t SGANNEp Friday,April 21,2017 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Friday,April 07,2017 Jim Regg OV- P.I.Supervisor SUBJECT: Mechanical Integrity Tests kX BP EXPLORATION(ALASKA)INC. )��,t I n 11"07 FROM: Bob Noble r` PRUDHOE BAY UNIT 11-07 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry M NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 11-07 API Well Number 50-029-20687-00-00 Inspector Name: Bob Noble Permit Number: 181-177-0 Inspection Date: 3/20/2017 Insp Num: mitRCN170321065509 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 11-07 Type Inj W TVD 8137 Tubing 701 676 671 679 i PTD 1 1811770 'Type Test SPT Test psi! 2500 ' IA 25 2501 2413 2362 BBL Pumped: 1 5,6 BBL Returned: 4.6 OA 22 345 1 454 540 Interval REQVAR P/F P ,--- Notes: /Notes: MIT-IA well as per AIO 4G.004. 1 x max anticapated injection pressure(1100 psi)every 2 years. L% SCANNED AUG 1 5 ?01 Friday,April 07,2017 Page 1 of 1 • 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday,March 22,2017 Jim Regg P.I.Supervisor w ^ SUBJECT: Mechanical Integrity Tests `A` . BP EXPLORATION(ALASKA)INC. ``� 11-07 FROM: Bob Noble - Z�` PRUDHOE BAY UNIT 11-07 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry r-'3 . NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 11-07 API Well Number 50-029-20687-00-00 Inspector Name: Bob Noble Permit Number: 181-177-0 Inspection Date: 3/20/2017 Insp Num: mitRCN170321065509 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 11-07 Type Inj W TVD 1 8137 j Tubing 701 1 676 671 679 PTD 1811770 Type Test SPT Test psi 2500 j IA 2500 I 2501 2413 2362 BBL Pumped: 5.6 BBL Returned: 4.6 OA 22 345 454 I 540 Interval REQVAR P/F P Notes: MIT-IA well as per AIO 4G.004. 1 x max anticapated injection pressure(1100 psi)every 2 years. ✓ SCANNED AUG 3 0 ZOI7, Wednesday,March 22,2017 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,February 27,2017 TO: Jim Regg P.I.Supervisor 1,",`-'. SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. 3� 11-07 3� FROM: Chuck Scheve 111 111 l PRUDHOE BAY UNIT 11-07 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry HS-U NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 11-07 API Well Number 50-029-20687-00-00 Inspector Name: Chuck Scheve Permit Number: 181-177-0 Inspection Date: 2/21/2017 Insp Num: mitCS170221145926 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Type Inj ! W TVD 8137 Tubing 970 969 965 963 Well 11-07 968 PTD 1811770 Type Test SPT Test psi 2034 IA 288 2491 2428 2380 2324 -------------- — -------------------------- -- BBL Pumped: !BBL Returned: OA 285 561 645 725 832 ti., Interval REQVAR P/F F ‘7- Notes: /Notes: Tested per AIO 4G.004. Well showed obvious IA x OA communication. DHD lost track of bbls pumped and bbls returned. SCANNED APR 2 8 2017 Monday,February 27,2017 Page 1 of 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com> Sent: Sunday, February 26, 2017 4:14 PM To: AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FS2 OSM;AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Field OTL;AK, OPS FS2 Facility OTL; AKOpsProdEOCTL;AK, OPS PCC Ops Lead;AK, GWO SUPT Slickline;AK, GWO SUPT Special Projects; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists;AK, RES GPB West Wells Opt Engr;G GPB FS2 Drillsites; 'chris.wallace@alaska.gov'; Shrider,James Cc: AK, GWO DHD Well Integrity;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Worthington,Jessica; Dickerman, Eric; Regg,James B (DOA);Odom, Kristine;AK, GWO Completions Well Integrity;AKIMS App User; Ross, Matthew; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Pettus,Whitney;Tempel, Troy;Worthington,Aras J;AK, GWO SUPT Well Integrity Subject: UNDER EVALUATION:Injector 11-07 (PTD#1811770) Further diagnostics for IAxOA communication All, Water Injector 11-07 (PTD#1811770)has known inner annulus by outer annulus communication and operates under Administrative Approval MO 4G.004. The well passed a non-witnessed MIT-IA on 1/22/17,prior to pursuit of the AA. A witnessed MIT-IA on 2/21/17 failed to exhibit stabilization.The suspected cause of the failed test is decreased injection rate, starting approximately a day prior to the test. The AOGCC have granted permission to place the well back online for further diagnostics,including a non-witnessed MIT-IA once the injection rate is stable.Pending satisfactory results,a witnessed MIT-IA re-test will be scheduled. The well has been reclassified as Under Evaluation Plan Forward: Evaluate Possible IAxOA Communication 1. Ops: Place well on injection. 2. Wellhead Tech: Perform PPPOT-IC 3. DHD: Bleed off IA& OA to—20psi. Perform MIT-IA to 2500 psi 4. WIE: Additional diagnostics&review MIT results 5. DHD: Perform state witnessed MIT-IA to 2500 psi Please reply if in conflict with proposed plan. Matt Ross (Alternate: Josh Stephens) SEWEDAPP. 0 7 2E, Well Integrity Engineering Office 907-659-8110 Cell 907-980-0552 Harmony 4530 1 • • Wallace, Chris D (DOA) From: AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com> Sent: Friday, February 10, 2017 1:33 PM To: AK, GWO SUPT Well Integrity;AK, OPS FS2 OSM;AK,OPS FS2 DS Ops Lead;AK, OPS FS2 Field OTL;AK, OPS FS2 Facility OTL;AKOpsProdEOCTL;AK, OPS PCC Ops Lead;AK, GWO SUPT Slickline;AK, GWO SUPT Special Projects;Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists;AK, RES GPB West Wells Opt Engr;G GPB FS2 Drillsites; 'chris.wallace@alaska.gov';Shrider,James Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R;Worthington,Jessica; Dickerman, Eric; Regg,James B (DOA);Odom, Kristine;AK, GWO Completions Well Integrity;AKIMS App User; Ross, Matthew; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus,Whitney;Tempel, Troy;Worthington,Aras J Subject: RE: UNDER EVALUATION:Injector 11-07 (PTD#1811770) Possible Anomalous IAxOA Behavior All, Water Injector 11-07 (PTD#1811770)exhibits slow inner annulus by outer annulus communication and was made Under Evaluation on 01/15/17. Since then the well passed an MIT-IA to 2,404 psi, indicating the tubing and production casing are competent barriers. Outer annulus operating pressure is maintained below the Normal Operating Limit (NOL— formerly called MOASP)with infrequent bleeds. Request for Administrative Approval to continued operation of this well has been sent to the AOGCC. At this time the 28 day clock will be reset and will remain Under Evaluation for an additional 28 days or until AA approval is received. Please respond if in conflict with plan, Joshua Stephens s ��� �Q NIA:\ K 0 Well Integrity Engineer Office: 907-659-5766 Cell: 903-816-0183 Vr o From: AK, GWO SUPT Well Integrity Sent: Sunday, January 15, 2017 4:08 PM To: AK, GWO Well Integrity Well Information; AK, OPS FS2 0 • , • . OPS FS2 DS Ops Lead; AK, OPS FS2 Field OTL; AK, OPS FS2 Facility OTL; AKOpsProdEOCTL; AK, OPS PCC Ops Lead; AK, •, s UPT Slickline; AK, GWO SUPT Special Projects; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; A', s'S EOC Specialists; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Sinnok, Ralph; 'chris.wallace@alaska.gov' Cc: AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, OPS FF Well Ops Co , Rep; Sternicki, Oliver R; Worthington, Jessica; Dickerman, Eric; 'Regg, James B (DOA)'; Odom, Kristine; AK, GWO Comple • Well Integrity; AKIMS App User; Ross, Matthew; Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Cor- • Obrigewitch, 1 • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Sunday, January 15, 2017 4:08 PM To: AK, GWO Well Integrity Well Information;AK, OPS FS2 OSM;AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Field OTL;AK, OPS FS2 Facility OTL;AKOpsProdEOCTL; AK, OPS PCC Ops Lead; AK, GWO SUPT Slickline; AK, GWO SUPT Special Projects; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Sinnok, Ralph; 'chris.wallace@alaska.gov' Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R;Worthington, Jessica; Dickerman, Eric; Regg, James B (DOA); Odom, Kristine; AK, GWO Completions Well Integrity; AKIMS App User; Ross, Matthew; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney;Tempel, Troy; Worthington, Aras J Subject: UNDER EVALUATION:Injector 11-07 (PTD #1811770) Possible Anomalous IAxOA Behavior Attachments: Injector 11-07 (PTD#1811770) TIO and Injection Plots.docx All, Water Injector 11-07 (PTD#1811770) began exhibiting possible anomalous inner by outer annulus behavior on 01/14/17 after a nitrogen capwas inserted into the inner annulus. The well has been reclassified as Under Evaluation to progress g p g further diagnostics. Plan Forward: Evaluate Possible IAxOA Communication 1. Wellhead Tech: Perform PPPOT-IC 2. DHD: Perform MIT-IA to 2500 psi 3. WIE: Additional diagnostics SCANNED JAN 2 82o2 Recent TIO and Injection plots have been included for reference. Thanks, Jack Lau (Alternate:Adrienne McVev) BP Alaska-Well Integrity Superintendent W: 907.659.5102 C: 907.943.0296 H: x2376 1 • • • Injector 11-07(PTD#1811770) TIO Plot January 15,2017 Well I,-01 3000 +166 0O 0 00 004 ♦ 0004 ,, 000 O 161516 162216 102916 110516 11121E 11.191E 11.7616 140116 1212E 121':11 127<16 `71110 0,.'07'17 0':ll Injection Plot January 15,2017 w�ll 11a, L000 EOG B00 .1� °G 2 - 6941000 9W 6W 5000 V -MI 4K -GI -0,4, 9r 200 1015.16 462216 162916 119516 1112116 111916 117610 120116 12/1616 12117116 17/7116 17.31/16 0197:17 014' • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,March 08,2016 TO: Jim Regg P.LSupervisor -Perlf 31q1((0 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. 11-07 FROM: Lou Grimaldi PRUDHOE BAY UNIT 11-07 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry_J NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 11-07 API Well Number 50-029-20687-00-00 Inspector Name: Lou Grimaldi Permit Number: 181-177-0 Inspection Date: 2/23/2016 - Insp Num: mitLG160223151706 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 11-07 - Type Inj W TVD 8137 Tubing 607 608 607 , 607 - PTD 1811770 Type Test SPT Test psi 2034 - IA 190 2504 - 2470 2458 - Interval 4YRTST P/F P / OA 13 66 • 68 • 68 • Notes: 4.3 bbl's Diesel pumped,4.6 returned.Good solid 4 year MIT.All pertinent paperwork provided prior to test. SCANNED SEP 2 6 2016 Tuesday,March 08,2016 Page 1 of 1 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Tuesday, February 23, 2016 2:34 PM To: AK, OPS FS2 OSM;AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Field OIL; AK, OPS FS2 Facility OIL; AK, OPS PCC EOC IL; AK, D&C Wireline Operations Superintendent;AK, D&C Well Services Operations Superintendent; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB East Wells Opt Engr; AK, OPS PCC Ops Lead; AK, OPS EOC Specialists; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Sinnok, Ralph; Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator;AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers,Jessica; Dickerman, Eric; Regg,James B (DOA) Subject: OPERABLE:Injector 11-07 (PTD#1811770)AOGCC MIT-IA Passed Attachments: Injector 11-07 (PTD#1811770) TIO Plot.docx All, Injector 11-07 (PTD#1811770) passed an AOGCC witnessed MIT-IA on February 23, 2016. The passing test confirms two competent barriers in the wellbore. During the MIT-IA there was no signs of Inner by outer annulus communication. A passing Positive Pressure Pack-off test on the Inner casing was performed on February 4, 2016 showing no signs of communication through the wellhead. The well is reclassified as Operable. A copy of the TIO plot has been included for reference. Please call with any questions. Thank you, Kevin Parks �eA�NEU MAR 1 2Q1� G1� (Alternate WhitneyWhitneyPerties' BP Alaska-Well Integrity Coordinator �/��!� Global Werganizationlls O Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Sunday, January 31, 2016 11:46 PM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Field OTL; AK, OPS FS2 Facility OTL; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East.Wells Opt Engr; AK, OPS EOC Specialists; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Sinnok, Ralph; 'chris.wallace@alaska.gov'; G GPB FS2 Drillsites Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; 'Regg, James B (DOA) (iim.re•g@alaska.gov)'; AK, D&C Well Integrity Coordinator; Dickerman, Eric Subject: UNDER EVALUATION: Injector 11-07 (PTD #181177b)Ro ntial IAxOA Communication All, Water Injector 11-07 (PTD#1811770)was put on injection the beginning of January. The well has begun to exhibit inner by outer annulus communication after a nitrogen cap was applied to the inner annulus.At this time,the well has been reclassified as Under Evaluation to facilitate further diagnostics. 1 • . Injector 11-07(PTD#1811770)TIO Plot OW 0,6 ten. y r 0034 oa x:s ,.:.a �.s ua.s n,s o�xzu c ux,.a a,..n a o.,ns max a r,u,s i.x a ox a e,wu mmx o.vu o xx o,a<o�vs msi,s masx�.+au xo.�c eza s a,.rt ce.+xu�,sm crxx cr,xu�ovx s,�,:. • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Sunday,January 31, 2016 11:46 PM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Field OTL; AK, OPS FS2 Facility OTL; AK, OPS PCC EOC IL; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Sinnok, Ralph; Wallace, Chris D (DOA); G GPB FS2 Drillsites Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Regg, James B (DOA);AK, D&C Well Integrity Coordinator; Dickerman, Eric Subject: UNDER EVALUATION:Injector 11-07 (PTD#1811770) Potential IAxOA Communication Attachments: 11-07 Wellbore Schematic.pdf;Injector 11-07 TIO and INJ Plots 1-31-16.docx All, Water Injector 11-07 (PTD#1811770)was put on injection the beginning of January. The well has begun to exhibit inner by outer annulus communication after a nitrogen cap was applied to the inner annulus. At this time,the well has been reclassified as Under Evaluation to facilitate further diagnostics. Plan Forward: 1. Cameron: Perform PPPOT-IC to evaluate for communication through the wellhead 2. DHD: Perform MIT-IA to 2,500 psi 3. WIE: Additional screening as needed A copy of the TIO and Injection plots as well as a wellbore schematic drawing have been included for reference. Please call with any questions. Thank you, Laurie Climer SCANNED JUL 2 5 2016 (Filling in for Kevin Parks) BP Alaska-Well Integrity Coordinator GUN & al", Organizmt o;1 WIC Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator@BP.com 1 + • • Injector 11-07(PTD#18117700) TIO Plot Jan 31, 2016 We IIel V. aur" rm #_U nx }OA001 .0, I I 123z* u1e% Daus 01,7016 ,..,.. Injection Plot Vel ua .631 tl VA 336 1 N OZ • 9M -- E —61 —flab YS 10')!,15 1.07 IS I11lt .12115 — 153615 12WIS 7212'1 .2:115 1226*5 @3332% 0➢et% 0036% 0103% O!'3% XHVZE Ima.roject Well History File Cover,ge This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. i 2f L - J 1 7 Well History File Identifier Organizing (done) RESC.AN ~-Sided 1111111111111111111 I' ~escan Needed 1111I1I111111111111 DIGITAL DATA OVERSIZED (Scannable) . ~- ~ Grayscale items: o Poor Quality Originals: o Diskettes, No. o Maps: Other items scannable by large scanner o Other, NofType o OVERSIZED (Non-Scannable) o Other: o Logs of various kinds NOTES: o Other BY: BEVERLY ROBIN VINCENT SHERYL~INDY DATEY;J}-åJ. 151 Project Proofing 1111111111111111111 BY: BEVERLY ROBIN VINCENT SHERYL MARIA WIND~ DATEØ;;.?7ð..;2 151 Scanning Preparation -5- x 30 = 1c5ò + r2C/ = TOTAL PAGES lIe¡ BY: BEVERLY ROBI~ SHERYL MARIA WINDY DATE!/{). Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: /7-9 PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: * YES _ NO BEVER~INCENT SHERYL MARIA WINDY DATE:/-é/'I-t/5'/SI Ìè~ Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ~. NO BEVERLY ROBIN VINCE~ARIA WINDY DATE:/, 6 . /~~ ~ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS 'I""':' ~ () 1111111111111111111 DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) BY: BY: ReScanned (individual page [special attention] scanning completed) 111111111I11/111111 RESCANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: 151 General Notes or Comments about this file: Quality Checked (done) 111111111I111/11 ~I 12110/02Rev3NOTScanned.wpd STATE OF ALASKA • isSKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon [i Repair Well U Plug Perforations U Perforate U Other U , Bright Water Performed: Alter Casing ❑ Pull TubinC Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development Exploratory ❑ 181 -177 -0 . 3. Address: P.O. Box 196612 StratigraphiC I Service 0 6. API Number: Anchorage, AK 99519 -6612 50- 029- 20687 -00 -00 • 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028325 PBU 11 -07 - 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL, 11. Present Well Condition Summary: Total Depth measured 9472 feet . Plugs measured None feet true vertical 8986 feet Junk measured 9270 feet Effective Depth measured 9430 feet Packer measured See Attachment feet true vertical 8946.41 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 91.5# H-40 35 - 115 35 - 115 1490 470 Surface 2625 13 -3/8" 72# L -80 34 - 2659 34 - 2658.74 4930 2670 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner 1380 7" 26# L -80 8092 - 9472 7679.53 - 8986.17 7240 5410 Perforation depth Measured depth 9296 - 9312 feet l ° True Vertical depth 8819.55 - 8834.7 feet SCANNED �� �,. Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratori❑ Development ❑ • Service El Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPL❑ GSTOR ❑ • WINJ 19 WAG ❑ GINJ ❑ SUSP ❑ SPLUCJ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Nita Summerhays Email Nita.Summerhaysl�BP.com Printed Name Nita Summerha s Title Petrotechnical Data Technician „Rams Signatur ijintif ,� U // Phone 564 -4035 Date 5/30/2013 KW pDMS MAY 3 1 20 ,6//4/1_,3 , 4, Form 10 -404 Revised 10/2012 Submit Original Only • • Daily Report of Well Operations ADL0028325 - T /I /O = 400/440/20 Temp = Hot ( Brightwater Reservoir Sweep ® 0. Mobilize to 11 -07 and rig up 5/3/2013 ** *WSR continued on 5/4/13 * ** T /I /O = 400/440/20 Temp = Hot (Brightwater Reservoir Sweep Mod) ***WSR continued from 5/03/13*** Pumping brightwater chemicals down TBG while on water injection © 6,000 bwpd. Pumped 285 gal. EC9360A (surfactant). Average of 28.5 gph for 10 Hours. Pumped a total of 285 gal. since start of project. Pumped 1311 gal. EC9398A (polymer) Average of 138 gph for 9.5 Hours. Pumped a total of 1311 gal. since start of project. * *Establishing rates with proving pots * ** 5/4/2013 ** *WSR continued on 05/05/13 * ** T /I /O = 400/440/20 Temp = Hot (Brightwater Reservoir Sweep Mod) ***WSR continued from 5/04/13 * ** Pumping brightwater chemicals down TBG while on water injection @ 6,000 bwpd. Pumped 559 gal. EC9360A (surfactant). Average of 23.3 gph for 24 Hours. Pumped a total of 844 gal. since start of project. Pumped 2765 gal. EC9398A (polymer) Average of 115.2 gph for 24 Hours. Pumped a total of 4076 gal. since start of project. * *Establishing rates with proving pots * ** 5/5/2013 ** *WSR continued on 05/06/13 * ** T /I /O = 400/440/20 Temp = Hot ( Brightwater Reservoir Sweep Mod) * ** WSR continued from 5/05/13 * ** Pumping brightwater chemicals down TBG while on water injection @ 6,000 bwpd. Pumped 521.5gal. EC9360A (surfactant). Average of 21.8 gph for 24 Hours. Pumped a total of 1365.5 gal. since start of project. Pumped 2800 gal. EC9398A (polymer) Average of 116.7 gph for 24 Hours. Pumped a total of 6876 gal. since start of project. * *Establishing rates with proving pots * ** 5/6/2013 ** *WSR continued on 05/07/13 * ** • Daily Report of Well Operations ADL0028325 T /I /O = 400/440/20 Temp = Hot (Brightwater Reservoir Sweep Mod) * ** WSR continued from 5/05/13 * ** Pumping brightwater chemicals down TBG while on water injection @ 6,000 bwpd. Pumped 521.5gal. EC9360A (surfactant). Average of 21.8 gph for 24 Hours. Pumped a total of 1365.5 gal. since start of project. Pumped 2800 gal. EC9398A (polymer) Average of 116.7 gph for 24 Hours. Pumped a total of 6876 gal. since start of project. * *Establishing rates with proving pots * ** 5/6/2013 ** *WSR continued on 05/07/13 * ** T /I /O = 400/440/20 Temp = Hot (Brightwater Reservoir Sweep Mod) * ** WSR continued from 5/06/13 * ** Pumping brightwater chemicals down TBG while on water injection @ 6,000 bwpd. Pumped 502.5 gal. EC9360A (surfactant). Average of 22.8 gph for 21 Hours. Pumped a total of 1868 gal. since start of project. Pumped 2414 gal. EC9398A (polymer) Average of 109.7 gph for 22 Hours. Pumped a total of 9262 gal. since start of project. * *Establishing rates with proving pots * ** Valve position upon LRS departure, SV= closed, WV, SSV, MV =open, IA/OA =OTG 5/7/2013 FWHP 460/500/20 T /I /O = 400/440/20 Temp = Hot (Brightwater Reservoir Sweep Mod) * ** WSR continued from 5/06/13 * ** Pumping brightwater chemicals down TBG while on water injection © 6,000 bwpd. Pumped 502.5 gal. EC9360A (surfactant). Average of 22.8 gph for 21 Hours. Pumped a total of 1868 gal. since start of project. Pumped 2414 gal. EC9398A (polymer) Average of 114.9 gph for 22 Hours. Pumped a total of 9290 gal. since start of project. * *Establishing rates with proving pots * ** Valve position upon LRS departure, SV= closed, WV, SSV, MV =open, IA/OA=OTG 5/7/2013 FWHP 460/500/20 • • Daily Report of Well Operations ADL0028325 T /I /O = 400/440/20 Temp = Hot (Brightwater Reservoir Sweep Mod) *'`* WSR continued from 5/06/13 * ** Pumping brightwater chemicals down TBG while on water injection @ 6,000 bwpd. Pumped 502.5 gal. EC9360A (surfactant). Average of 22.8 gph for 21 Hours. Pumped a total of 1868 gal. since start of project. Pumped 2414 gal. EC9398A (polymer) Average of 114.9 gph for 22 Hours. Pumped a total of 9290 gal. since start of project. * *Establishing rates with proving pots * ** Valve position upon LRS departure, SV= closed, WV, SSV, MV =open, IA/OA =OTG 5/7/2013 FWHP 460/500/20 FLUIDS PUMPED GAL 1868 EC -9360A SURFACTANT 9290 EC -9398A POLYMER 11158 TOTAL Casing / Tubing Attachment ADL0028325 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H -40 35 - 115 35 - 115 1490 470 LINER 1380 7" 26# L -80 8092 - 9472 7679.53 - 8986.17 7240 5410 PRODUCTION 7488 9 -5/8" 47# L -80 33 - 7521 33 - 7159.31 6870 4760 PRODUCTION 813 9 -5/8" 47# S00-95 7521 - 8334 7159.31 - 7905.34 8150 5080 SURFACE 2625 13 -3/8" 72# L -80 34 - 2659 34 - 2658.74 4930 2670 TUBING 8632 4 -1/2" 12.6# L -80 32 - 8664 32 - 8220.23 8430 7500 • TUBING 21 4 -1/2" 12.6# L -80 8750 - 8771 8302.21 - 8322.21 8430 7500 I • • • Packers and SSV's Attachment ADL0028325 SW Name Type MD ND Depscription 11 -07 PACKER 8100 7624.93 4 -1/2" Baker S -3 Perm Packer 11 -07 PACKER 8100 7624.93 7" Baker Packer 11 -07 PACKER 8750 8240.21 4 -1/2" TIW HBBP Packer TITS = CMJ III IFETY NOTES: WELL REQUIRES A SSSV V "C = FMC A WHEN ON Ml. * ** 87' GAP FROM WLEG @ 8663' ACTUATOR = BAKER C 11 �O TO PKR @ 8750'. TBG TAIL PARTED @ 8771' KB. ELEV = 62' BF. ELEV = ? 1 DURING 04/08 RWO (SEE ASH) * ** KOP = 3900' 20" CONDUCTOR -I 80' I J Max I Angle = 32 °@ 6400' 91.5 #, H -40, Datum MD= 9343' ID = 19.124" , I 2107' I� 4 -1/2" HES X NIP, ID = 3.813" Datum TV D = 8800' SS 113 -3/8" CSG, 72 #, L -80 BTC, ID = 12.347" H 2659' Minimum ID = 3.813" @ 2107' 4 -1/2" HES X NIPPLE 9 -5/8" CSG, L -80 LTC XO TO SOO95 LTC BTRS I-J 7521' 8092'_I -17" BKR TIEBACK SLV, ID = 7.50" I I TOP OF 7" LNR I 8092' J 81 00' -1 9 -5/8" X 7" BKR LTP, ID = 6.313" I i II pit 8104' 1-19-518" X 7" LNR HGR, ID= 6.313" I 0 01 ►4 411 l 6 • i 0 4 9 -5/8" MILLOUT WINDOW (11 -07ST) 8287' - 8334' • •�• • . • ► •••••••••\ 8556' 4 -112" HES X NIP, ID= 3.813" ♦•••• • ••••••••• •••••••••••, •••••• 1 8577' -17" X 4 -1 /2" BK R S -3 PKR, ID = 3.870" ♦ • •• 8642' —I4 1 /2" HES X NIP, ID = 3.813" I ••••••••• % •• •i • •• � •� `C. 8664' —14-1/2" WLEG, ID = 3.958" •••••••••• ••••••••• 8750' 7 "X4- 1 /2 "TIWHBBP ••••••••■ ••••••••• •••••••••••••••••• PERM PKR, ID = 3.960" ►••••••••••••••••• •••••••••• ••••••••• ••••••••• ••••••••• 8771' 4 -1/2" PARTED TT, ••••••••• ► .e, ID = 3.958" ••••••••• 1 1� ►•••••••♦ ••••••••• �•�•�•�•�•�•�•�•�• .� 9215' -17" MARKER JOINT I ►••••••••••••••••• �. ••••••••••••• • •••• 19 -5/8" CSG, 47 #, S0095 LTC BTRS, ID = 8.681" H 9421 ••••••••••••••••• • 9270' 1 FISH - TBG TAIL � ••••••••••••••••• w /NIPS & WLEG ►� ■■- •-•-•■■ (04/17/08) PERFORATION SUMMARY 4 -1/2" TBG, 12.6 #, L -80 TCII, 8664' REF LOG: BHCS ON 08/06/92 .0152 bpf, ID = 3.958" ` ANGLE AT TOP PERF: 14° @ 9296' 4 -1/2" TBG, 12.6 #, L -80 TDS, 8771' Note: Refer to Production DB for historical pert data .0152 bpf, ID = 3.958" SIZE SPF INTERVAL Opn /Sqz DATE ..1t 3 -1/8" 4 9296 - 9312 0 08/21/92 I PBTD I-J 9432' I ���44��44% ;;;',► 7" LNR, 26 #, L -80 NSCC, .0383 bpf, ID = 6.276" H 9472' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 02//20/82 R35 ORIGINAL COM PLETION 11/17/08 ?/ PJC DRLG DRAFT CORRECTIONS WELL: 11 -07ST 08/09/92 N2ES SIDETRACK (11 -07ST) 11/18/08 GMD /PJC DRLG DRAFT CORRECTIONS PERMIT No: ir 1811770 04/17/08 N4ES RWO 02/14/11 MB /JMD ADDED SSSV SAFETY NOTE API No: 50- 029 - 20687 -00 05/04/08 JNA /PJC FISH -TT BTM (4/17/08 RWO) SEC 33, T11 N, R15E, 253 FNL & 81 FEL 05/29/08 RC /PJC CORRECTIONS 06/25/08 RC /PJC DRLG CORRECTIONS BP Exploration (Alaska) ! • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg / DATE: Thursday, April 19, 2012 P.I. Supervisor \ < t 4'(2 ((7,- SUBJECT: Mechanical Integrity Tests ((`� BP EXPLORATION (ALASKA) INC 11 -07 FROM: Jeff Jones PRUDHOE BAY UNIT 11 -07 Petroleum Inspector Src: Inspector Reviewed By: P.I. SuprvJJ NON CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 11 - 07 API Well Number 50 029 - 20687 - 00 - 00 Inspector Name: JeffJones Permit Number: 181 - 177 - Inspection Date: 4/15/2012 Insp Num: mitJJ120415163826 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 11-07 Type Inj W ' TVD 8137 IA 516 2320 - 2273 2257 ' 1 PTD I 1811770 - Type Test SPT Test psi ! 2034 , OA 92 233 • 233 230 - Interval 1 14 YRTST [P/F P ' Tubing � 1578 1578 • 1580 1580 • Notes: 2.6 BBLS methanol pumped. 1 well inspected, no exceptions noted. JUNt' Ur : ' Thursday, April 19, 2012 Page 1 of 1 • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 40, Anchorage, Alaska 99519 -6612 December 21, 2010 �A `ZU1 ffi, Mr. Tom Maunder Alaska Oil and Gas Conservation Commission + asion 333 West 7 Avenue ally .Te Anchorage, Alaska 99501 g 1 - /f Subject: Corrosion Inhibitor Treatments of GPB DS 11 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 11 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS -11 Date: 12/21/10 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement _ pumped cement date inhibitor sealant date ft bbls ft na gal 11 -01A 1921120 50029206440100 NA Sealed NA NA 6/25/2010 11 - 02 1811280 50029206490000 NA Sealed NA NA 6/25/2010 11 -03A 1911520 50029206660100 NA Sealed NA NA 6/25/2010 11 - 04A 1940230 50029204800100 NA Sealed NA NA 6/25/2010 11 -05A 1961570 50029206700100 NA Sealed NA NA 6/25/2010 11 - 06A 2042250 50029206740100 NA Sealed NA NA 6/25/2010 11 1811770 50029206877000 NA Sealed NA NA 6/25/2010 11 -08 1842290 50029212450000 NA Sealed NA NA 6/27/2010 11 -09A 1961280 50029214020100 NA 25 NA _ 42.50 6/29/2010 11 -10 1851590 50029213940000 NA 5 NA 28.90 6/30/2010 11 -11 1851410 50029213820000 NA Sealed NA NA 6/27/2010 11 -12 1841950 50029212120000 NA Sealed NA NA 9/12/2010 11 -13A 1921100 50029212290100 NA Sealed NA NA 9/12/2010 11 -16 1860780 50029215817000 NA Sealed _ NA NA 6/27/2010 11 -17A 2020320 50029215980100 NA Sealed NA NA 6/27/2010 11 -18 1861120 50029216070000 NA Sealed NA NA 6/27/2010 11 -22A 1950870 50029220356000 NA 1 NA 9.35 7/1/2010 11 -23A 1940810 50029216100100 NA Sealed NA NA 7/1/2010 11 -24A 1932040 50029216230100 NA Sealed NA NA 6/26/2010 11 -25A 1990820 50029204880200 NA Sealed NA NA 6/26/2010 11 -26 1861340 50029216280000 NA 1.9 NA 5.10 6/28/2010 11 -27 1861480 50029216380000 NA 3.5 NA 11.90 6/28/2010 11 -28A 2000950 50029219580100 NA Sealed NA NA 6/28/2010 11 -29 1940250 50029224660000 NA 0.2 NA 1.70 6/28/2010 11 - 31A 1961830 50029225090100 NA 1.4 NA 6.80 6/28/2010 11 - 32 1941310 50029225120000 NA 6.7 NA 59.50 6/30/2010 11 -33 1940900 50029224900000 NA 0.5 NA 2.55 6/30/2010 11 -34 1941380 50029225160000 NA 0.5 NA 3.40 11/27/2009 11 - 35 1940650 50029224760000 NA 0.6 NA 5.10 6/30/2010 11 -37 1961740 50029227160000 NA 4 NA 42.50 7/1/2010 11 -38A 1982160 50029227230100 NA 2.1 NA 22.10 6/28/2010 • MEMORANDUM To: JimRegg ~E,~ ~ ~~Z7~c~~ P.I. Supervisor ~ ~ FROM: Lou Grimaldi Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, May 27, 2008 SLBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC t t -07 PRUDHOE B.4Y LNIT 1 I-07 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~_~~.~`~- Comm Well Name: PRUDHOE BAY UNIT 11-07 Insp NUm: mitLG080503 171 1 55 Rel Insp Num: API Well Number 50-029-20687-00-00 Inspector Name• Lou Grimaldi Permit Number: 18t-177-0 Inspection Date: 5'3i2oos Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. t ~ -07 ~--- -- - YP J TVD -- ~ -- --- -- ell tatrno `TYPeIn'. w P _si37 i-- 2200 'i zt9o __ ' ~~60 /r IA 30 ?260 -- P.T T eTest SPT ,Test si OA o o ', o _! o -- _ _ __ _ .- -- r _-_--- -_ Interval WRKOVR p~F P ~ TUblrig 620 640 640 I, 630 NOteS' S.1 Bbl's pumped. Post workover initial test. ~Nl MAY ~ ~ 2 Tuesday, May 27, 2008 Page I of I ~ O L~ V 1o A Y L. L.i` STATE OF ALASKA S- ~~ ALl~4 OIL AND GAS CONSERVATION COM ION MAY ~ 9 2008 REPORT OF SUNDRY WELL OPERATIOI~ska Oil & Gas Cons. Commission Anr~hnr~no 1. Operations Performed: ^ Abandon ®Repair Well - ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing - ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 181-177 - 3. Address: ®Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20687-00-00 ' 7. KB Elevation (ft): 62, _ 9. Well Name and Number: PBU 11-07 ST- 8. Property Designation: 10. Field /Pool(s): _ ADL 028235 - Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 9472 feet true vertical 8986 feet Plugs (measured) None Effective depth: measured 9428 feet Junk (measured) 9257' true vertical 8945 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 80' 80' 1490 470 Surface 2659' 13-3/8" 2659' 2659' 5380 2670 Intermediate 8270' 9-5/8" 8270' 7845' 6870 4760 Production Liner 1380' 7" 8092' - 9472' 7680' - 8986' 7240 5410 ~~N MAY ~ ~ 2008 Perforation Depth MD (ft): 9296' - 9312' Perforation Depth TVD (ft): 8820' - 8835' 4-1/2", 12.6# L-80 8771' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker S-3 Packer 857T 7" x 4- 1/2" TIW HBBP PERM Packer 8750' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: ~ ~~~-~, t~A~ ~ ~ ~nt)~ 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ^ Development ®Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ^ Oil ^ Gas ®WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or wA if C.O. Exempt: Contact Mackie Derrick, 564-5891 308-090 Printed Name Sondra Stewman Title Drilling Technologist Prepared By Name/Number: ~~ 5 ~ Sign ure Phone 564-4750 Date ~ [ Sondra Stewman, 564-4750 Form 10-404 Revised 04/2006 ~ Submit Original Only ORIGINAL ~~~~ TREE _ ~ FMC GEN 2 WELLHEAD = FMC ~.- ACTUATOR= AXELSON KB. ELEV - ~ 62 BF. ELEV =_._ ~ KOP = 3900' Max Angle = 32 @ 6600' Datum MD = 9343' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" I-~ 2659' 4-112" 12.6# L-80 TCII Tbg, Ifl = 3.958" TOP OF 7" LNR ~-~ 8092' 9-5/8" CSG, 47#, L-80, ID = 8.681" I 8274' 9-518" MILLOUT SECTION 8287' - 8334' CEMENT WINDOW 8274' Minimum ID = 3.725" @ 8798' 4-1 /2" PARKER SWN NIPPLE 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I-I 8811' PERFORATION SUMMARY REF LOG: BHCS ON 08/06!92 ANGLE AT TOP PERF: 14 @ 9296' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-1/8" 4 9296 - 9312 O 08/21/92 PBTD 9430' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 9472' DATE REV BY COMMENTS DATE REV BY COMMENTS 2/82 ORIGINAL COMPLETION 04/17/08 N4ES RWO 08/08/92 RWO 04/19/08 /TLH CORRECTIONS 10/28/01 RN/TP CORRECTIONS 05/04/08 JNA/PJC FISH-TBG TAIL BTM (04/17/08 R~ 05/16/06 RCT/TLH PX PLUG SEl- 09/29/06 RDW/PJC WAVER SAFETY NOTE (8!14/06} 10/13/06 RCT/TLH PX PLUG PULLED 9257' FISH- TBG TAIL w / NIPPLES &WLEG (04/17/08 RWO) PRUDHOE BAY UNIT WELL: 11-07 PERMTf No: €1811770 API No: 50-029-20687-00 SEC 33, T11 N, R15E, 744.21 FEL 3588.92 FNL BP Exploration (Alaska) 8100' I--17" X 9-5/8" BAKER LNR PKR $' 4-1;2°' X NIPPLE, iD = 3.813" $577`.... - 7" x 4-112" BAKE~fi S-3 PKR, $642' 4-112" X NIPPLE, ID = 3.813" $663' 4-1/2" WLEG 8750' 7" X 4-1/2" TNV HBBP PERM PKR, ID = 3.960" 8771' 4-1/2" TT. ID = 3.958" BP EXPLORATION Operations Summary Report Page 1 of 4 Legal Well Name: 11-07 Common Well Name: i 1-07 Spud Date: 8/3/1992 Event Name: WORKOVER Start: 4/11/2008 End: 4/17/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/17/2008 Rig Name: NABORS 4ES Rig Number: Date j From - To Hours ~ Task I Code ~ NPT Phase Description of Operations __ - - - __ 4/12/2008 03:00 - 06:00 3.00 RIGD P PRE Scope down derrick. Lay over derrick. Prepare to move tral~i rig to 11-07•from 11-08. 06:00 - 10:00 4.00 RIGU P PRE Spot sub, pits and pipe shed. Raise derrick to half mast. Scope derrick. Accept rig at 10:00-hrs. 10:00 - 12:30 2.50 WHSUR P DECOMP Take on seawater to pits. Hook up circulating lines to IA., P f BPV and HSE FasDril plug at 8775' to 1500-psi for 10-charted 12:30 - 12:45 0.25 WHSUR P DECOMP PJSM: Review nipple down tree procedure. 12:45 - 14:30 1.75 WHSUR P DECOMP Nipple down tree and set back. Inspect top hanger threads. Screw in 5-3/4" RH Acme XO. Remove XO. Good threads. 14:30 - 14:45 0.25 BOPSU P DECOMP PJSM: Review nipple up BOPE procedure. 14:45 - 18:00 3.25 BOPSU P DECOMP NU BOPE. Paged AOGCC inspectors at 15:30-hrs. to notify of impending BOPE testing starting in 3 hrs. RU test equipment, MU test joints, seviced mud cross. 18:00 - 23:00 5.00 BOPSU P DECOMP Held crew change and performed pre-tour checks of PVT equipment and derrick. Pressure tested BOPE per BP/AOGCC requirements to 250-psi Lo/4000-asi Hi. Tested annular preventer to 250-psi Lo/3500-psi Hi. Tested VBR's with 3-1/2" and 4-1/2" test joints and annular preventer with 3-1/2" test joint. Chuck Scheve waived states right to witness BOPE testing. 23:00 - 00:00 1.00 WHSUR P DECOMP RU blanking plug pulling tool and XOs. Pulled and LD blanking plug. RU lubricator and extension, tested to 500 psi. 4/13/2008 00:00 - 01:00 1.00 WHSUR P DECOMP Pulled BPV. RD and LD lubricator. 01:00 - 03:00 2.00 KILL P DECOMP Reverse circulated through tubing cut at 8720'. Pumped 53 bbls seawater at 3 bpm and 360 psi. Recovered about 40 bbls diesel from tubing until clean seawater returns. Took returns to tiger tank. RU to pump the long way. Circulated through tubing cut at 8720'. Pumped 166 bbls seawater at 4 bpm and 250 psi. Recovered about 120 bbls diesel in tiger tank, until clean seawater returns. Shut down pumping and monitored well for 30 minutes; well static. 03:00 - 05:00 2.00 PULL P DECOMP MU landing joint with closed TIW valve. BOLDS. Pulled tubing , hanger to rig floor with 128k PU. PU weight fell to 105k Ib after hanger came free. yoke out and LD tubing hanger. 05:00 - 07:30 2.50 PULL P DECOMP Circulated bottoms up from just above tubing cut depth of 8720'. Pumped seawater at 5 bpm and 220 psi. Tubing flowing back when circulating ceased. Mix and pumped 15-Bbls. of 8.7-ppg NaCI brine down tubing. 07:30 - 10:30 3.00 PULL P DECOMP POH laying down 4-1/2" completion tubing 1 x 1 through pipe shed while spooling single control line w/Schlumberger spooler. 53 jts. and SSSV laid down at 10:30-hrs. 10:30 - 18:00 7.50 PULL P DECOMP Continue POH laying down 4-1/2" completion tubing 1 x 1 through pipe shed. Found hole apprx. 9' from pin end in 183rd. joint layed down which matches up with Kinley caliper log. Recovered 217 joints 4-1/2" tubing, 56 ss control line bands and 16.69' cut joint. Tubing cut was clean and flared to about 5". Photos on S-Drive. LD tubing handling tools and RD handling equipment. 18:00 - 20:00 2.00 CLEAN P DECOMP Held crew change and performed pre-tour checks of PVT equipment and derrick. Cleared and cleaned rig floor. PU dress-off BHA #1: washover shoe, wash pipe extensions, dress off mill, boot basket, 7" scraper, oil jar, POS, and 9 x DC. Printed: 5/15/2008 9:18:17 AM • BP EXPLORATION Page 2 of 4 Operations Summary Report Legal Well Name: 11-07 Common Well Name: 11-07 Spud Date: 8/3/1992 Event Name: WORKOVER Start: 4/11/2008 End: 4/17/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/17/2008 Rig Name: NABOBS 4ES Rig Number: Date From - To ', Hours Task Code NPT Phase - -- 4/13/2008 20:00 - 21:00 . 1.00 CLEAN P 21:00 - 00:00 4/14/2008 00:00 - 04:15 04:15 - 06:00 06:00 - 06:30 06:30 - 07:30 07:30 - 09:00 09:00 - 10:30 10:30 - 15:00 15:00 - 15:30 15:30 - 18:00 18:00 - 20:30 20:30 - 21:00 21:00 - 23:15 23:15 - 00:00 4/15/2008 00:00 - 03:15 3.00 CLEAN P 4.25 CLEAN P Description of Operations DECOMP Held weekly safety meeting with all night rig personnel. Discussed Safety Alerts, STOP observations, and individuals' safety concerns. DECOMP RIH, picking up 3-1/2" drill pipe. 63 joints 3-1/2" DP PU ~ 00:00 hrs. Fluid level at calculated pipe displacement. DECOMP Continued RIH with dress-off BHA #1, PU 3-1/2" DP. Held well control {D1) drill while RIH. Averaged about 30-35 jt/hr RIH. Well fluid level at calculated displacement. Suspended RIH just above 7" liner top, with zoo its run. 1.75 CLEAN P DECOMP Slipped and cut drill line. 0.50 CLEAN P DECOMP Held crew change and performed pre-tour checks of PVT equipment and derrick. 1.00 CLEAN P DECOMP Held weekly HSE meeting with daylight crew. Reviewed safety incidents from past two weeks and also SOP for 'Risk Mitigation Procedure for Replacing Casing Packoffs". Emphasized the use of a 2" bleed line connected to the OA and the Tiger Tank. 1.50 CLEAN P DECOMP RIH w/singles of DP and eased through 7" liner top at 8100'. Did not notice and dragging while going through liner top. Proceeded on in hole and tagged top of tubing stub at 8724' DPM. 1.50 CLEAN P DECOMP Kelly up and establish milling parameters: P/U Wt. = 147K, S/O Wt. = 127K, 3.5-bpm C~3 600-psi, free torque = 2300 ft.-Ibs. 60-RPM. Ease down on tubing stub and commence milling with 2K WOM. Mill on stub with WOM varying from 2K to 20K, RPM varying from 40 to 90, pump rate from 2.0-bpm to 5.0-bpm with no increase in torque above 2300 ft.-Ibs. and no penetration rate. Diagnosis is that "K" anchor is spinning in latch receptacle. l,o a oI~T~ rate wii O Superintendent and RWO engineer on plan forward. 4.50 CLEAN P DECOMP POH standing drill pipe and drill collars in derrick and UD BHA #1. 0.50 CLEAN P DECOMP UD BHA #1. 2.50 CLEAN P DECOMP PUMU BHA #2: Type D spear, XO, LBS, oil jar, 9 x DC, POS. 2.50 CLEAN P DECOMP Held crew change and performed pre-tour checks of PVT system and derrick. RIH with BHA #2 on 90 stands 3-1/2" DP. Carefully entered 7" liner with no restriction. 0.50 CLEAN P DECOMP PU kelly and established parameters: PU 145k Ib, SO 125k Ib, Rot 133k Ib, 4 bpm, 950 psi, 15 rpm, 100a, 2000 Ib-ft. Tagged tubin stub at 8724' DPM. No rotation, SO to 140k Ib, then PU to 195k Ib to set grapple. SO to 140k Ib, made 13 RH rotations. Torque increased to 120a. PU weight at 145k Ib, indicating K-anchor released. SO to 140k Ib to reengage K-anchor, then PU to 195k Ib. SO to 140k Ib, made 12 RH rotations. Returned to original PU weight of 145k Ib, confirming K-anchor free. 2.25 CLEAN P DECOMP Circulated bottoms up from just above packer depth at 8750'. Pumped total of 535 bbls at 4 bpm and 990 psi. Monitored well - stable. 0.75 CLEAN P DECOMP POH, standing back 3-1/2" DP. 3.25 CLEAN P DECOMP Continued POH, standing back 3-1/2" DP. LD 3 x 4-3/4" DC, stood back 2 stands 4-3/4" DC. Well took 1 bbl seawater over calculated displacement. Printed: 5/15/2008 9:18:17 AM • BP EXPLORATION Operations Summary Report Page 3 of 4 Legal Well Name: 11-07 Common Well Name: 11-07 Spud Date: 8/3/1992 Event Name: WORKOVER Start: 4/11/2008 End: 4/17/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/17/2008 Rig Name: NABOBS 4ES Rig Number: Date From - To ~~, Hours Task Code ~ NPT Phase Description of Operations 4/15/2008 03:15 - 06:00 2.75 CLEAN P DECOMP LD spear BHA #2. Recovered 23.05' 4-1/2" cut joint, 6.09' 4-1/2" pup joint, and 1.17' K-anchor. Packer at 8755'. PU junk mill BHA #3: 3.7" mill, bit sub, XO, 8 jts PAC DP, XO, boot baskets, bit sub, oil jar, 6 x DC, and POS. 06:00 - 06:30 0.50 CLEAN P DECOMP Held crew change and performed pre-tour checks of PVT system and daily derrick inspection. Serviced drawworks, blocks and crown. 06:30 - 08:00 1.50 CLEAN P DECOMP RIH w/DP from derrick to 3250'. 08:00 - 09:30 1.50 WHSUR P DECOMP PJSM. PUMU 9-5/8" halco RTTS packer with storm valve. Set acker at 33' below rota table. P/T packer from above to 1000-psi for 10-charted minutes in preparation to changeout tubing spool and casing packoff. POH UD running tool. 09:30 - 11:00 1.50 BOPSU P DECOMP PJSM. ND BOPE and set back on stump. 11:00 - 11:30 0.50 WHSUR P DECOMP PJSM. Pick up /make up retrieving tool, pull 26K to retrieve pack off, OK. 11:30 - 13:00 1.50 WHSUR P DECOMP PJSM. Install new s 13:00 - 13:30 0.50 WHSUR P DECOMP PJSM. Test pack off to 5000 psi, OK. 13:30 - 15:00 1.50 BOPSU P DECOMP PJSM. N/U BOPE. 15:00 - 15:30 0.50 BOPSU P DECOMP PJSM. Pressure test breaks on BOPE ~ 250 / 4000 psi, OK. 15:30 - 16:00 0.50 BOPSU P DECOMP PJSM. Pull test plug, set wear bushing. (8 15/16" ID) 16:00 - 16:30 0.50 CLEAN P DECOMP PJSM. RIH (1) jt DP, engage Halliburton bridge plug & release same, UD bridge plug. 16:30 - 18:00 1.50 CLEAN P DECOMP RIH with junk mill BHA #3 on 3-1/2" DP. 18:00 - 18:30 0.50 CLEAN P DECOMP Held crew change and performed pre-tour checks of PVT equipment and derrick. Continued RIH with junk mill BHA #3 on 3-1/2" DP. 18:30 - 19:45 1.25 CLEAN P DECOMP PU kelly and established parameters: PU 139k Ib, SO 126k Ib, Rot 133k Ib, 50 rpm, 120a, 2400 Ib-ft, 4 bpm, 720 psi. Tagged FasDril olug at 8769' DPM. Rotated on plugs with 2k WOB, lost fluid returns after less than 5 minutes. Made two connections, chased plug remnants out end of tailpipe to mill de th of 8 ' (WLEG 8811'). 19:45 - 00:00 4.25 CLEAN P DECOMP Held PJSM. Blew down and set back kelly. POH, LD 3-1/2" drill pipe. Added about 120 bbl/hr seawater to well, on continuous hole fill. Round-tripped one vac truck with seawater. 154 jts LD at 00:00 hrs. 4/16/2008 00:00 - 02:30 2.50 CLEAN P DECOMP Continued POH, LD 3-1/2" drill pipe. Added about 120 bbl/hr seawater to well, on continuous hole fill. Round-tripped one vac truck with seawater. LD total of 272 jts DP. 02:30 - 04:00 1.50 CLEAN P DECOMP LD mill and 8 'ts PAC DP. LD remainder of mill BHA #3 and 6 x 4-3/4" DC. Pulled wear ring. Cleared and cleaned rig floor. 04:00 - 06:00 2.00 BUNCO RUNCMP RU to run 4-1/2" 12.6# L-80 TC-II tubing.. RU torque turn equipment and single joint compensator. 06:00 - 06:30 0.50 BUNCO RUNCMP Service rig, check PVT system, crown o matic, OK. Perform daily derrick inspection. 06:30 - 12:30 6.00 BUNCO WAIT RUNCMP Wait on WLEG / X nipple assembly w/ RHC-M to be made up and sent to rig. Constant hole fill. 12:30 - 18:00 5.50 BUNCO RUNCMP M/U completion assembly including WLEG, pups, x nipples and packer as per procedure on 4 1/2" 12.6# L-80 TCII tubing. Baker Lok all connections below packer. Torque turn all TCII connections to 3850 ft/Ibs. Using Jet Lube seal guard on all TCII connections. 18:00 - 00:00 6.00 BUNCO RUNCMP Held crew change and performed pre-tour checks of PVT Printed: 5/15/2008 9:18:17 AM BP EXPLORATION Page 4 of 4 Operations Summary Report Legal Well Name: 11-07 Common Well Name: 11-07 Spud Date: 8/3/1992 Event Name: WORKOVER Start: 4/11/2008 End: 4/17/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/17/2008 Rig Name: NABOBS 4ES Rig Number: Date I From - To Hours ~ Task Code NPT I' Phase Description of Operations 4/16/2008 18:00 - 00:00 6.00 BUNCO RUNCMP equipment and derrick. Continued running 4-1/2" 12.6# L-80 TC-II tubing. Utilized torque turn to 3850 Ib-ft and applied Jet Lube Seal Guard compound. Maintained continuous hole fill with charge pump, adding about 120 bph seawater. 4/17/2008 00:00 - 01:00 1.00 BUNCO RUNCMP Continued running 4-1/2" 12.6# L-80 TC-II tubing. Utilized torque turn to 3850 Ib-ft and applied Jet Lube Seal Guard thread compound. Ran total of 206 jts tubing plus accessories. 01:00 - 02:30 1.50 BUNCO RUNCMP MU tubing hanger, TC-II x IF XO and landing joint with closed TIW valve. Maintained continuous hole fill until about 15 minutes prior to landing hanger. PU weight 107k Ib, SO 95k Ib. RU air tugger line around landing joint to align hanger through BOP stack and tubing spool. SO, landed tubing hanger uneventfully and RILDS. 02:30 - 06:00 3.50 BUNCO RUNCMP Pumped 135 bbls seawater (120 deg F) down IA at 3 bpm and 60 psi. Pumped 360 bbls hot seawater with 0.6% EC1124A corrosion inhibitor down annulus at 3 bpm and 60 psi. Had about 10% fluid returns. 06:00 - 07:00 1.00 BUNCO RUNCMP Service rig, check crown o matic, PVT system, OK. Perform daily derrick inspection, OK. 07:00 - 09:30 2.50 BUNCO RUNCMP PJSM. Bullhead 120 bbls diesel down the I/A ~ 3 bpm / 300 psi. Bullhead 35 bbls diesel down the tubing C~3 3 bpm / 300 psi. 09:30 - 11:30 2.00 BUNCO RUNCMP PJSM: Droo rod and ball. Line up w/diesel and Little Red Services and pressure test tubing /set packer w/ 4000 psi / 30 minute test charted ood test. Bleed Tubing to 1500 psi and ressure test I/A and to of acker to 4000 si / 30 minutes monitoring O/A during test. Good test w/ no indication of communication with O/A. Bleed off all pressure. 11:30 - 13:00 1.50 BOPSU P RUNCMP PJSM. Set two way check valve and test C~ 3500 psi from the top for 15 minutes /charted /good test. N/D BOPE. 13:00 - 18:00 5.00 WHSUR P RUNCMP PJSM. N/U adapter flange and tree. Test tree /flange hanger to 5000 psi / 15 minutes /good test. Secure well, release rig C~ 1800 hours, 04-17-2008. Printed: 5/15/2008 9:18:17 AM Digital Well File • • Well: 11-07 Well History Well Date Summary 11-07 3/17/2008 T/IA/OA= SSV/0/0 Temp=cold PPPOT-T (PASS) PPPOT-IC (PASS) (Pre RWO) PPPOT-T RU 2 HP bleed tools onto THA 50 psi bleed to 0 psi. Pressured to 5000 psi for 30 minute test, 4950/ 15 minute, 4950/ 30 minute. Bleed void to 0 psi RD test equipment. Cycle and torque LDS "Standard style" all functioned with no problems. PPPOT-IC RU 1 HP bleed tools onto IC test void 50 psi to 0 psi. Pressured to 3500 psi for 30 minute test, 3400/ 15 minutes, 3400/ 30 minutes. Bleed IC void to 0 psi, RD test equipment. Cycle and torque LDS " Standard style" all functioned (1) LDS bent but will cycle & (1) G/N @ 9:00 position cracked needs to be changed out during RWO, all functioned good with no problems. 11-07 3/19/2008 *** WELL SI ON ARRIVAL, SSV DUMPED *** (drift for fasdrill/jetcut) DRIFTED W/ 3.80 CENT & S-BAILER...TAGGED XN-NIP @ 8790' SLM. NO PROBLEMS ENCOUNTERED.RDMO *** WELL LEFT SI, DSO NOTIFIED OF WELL STATUS *** 1 f-07 3/26/2008 T/I/0=120NacNac. Temp=Sl. T & IA FL's pre-Eline (RWO prep). T FL @ 1000' (16 bbls). IA FL NS (<5 bbls). 11-07 3/27/2008 ****WELL SHUT-IN ON ARRIVAL. T/I/0=90/0/0.**** E-LINE SET HES 3.65" OD FASDRILL BRIDGE PLUG MID-ELEMENT AT 8780 FT. DEVIATION AT PLUG SET 17 DEGREES. WAITING ON LRS TO ARRIVE TO TEST PLUG TO 3000PSI ***JOB CONTINUED ON 29-March-20008.*** 11-07 3/28/2008 T/I/0= 125/0/0 Temp= S/I Assist E-line, CMIT TxIA C~3 3500 psi. (RWO prep) Pumped 45 bbls. meth down TBG, standby for SLB to set another plug, Pumped 24.4 bbls of 60/40 meth down TBG to reach test pressure, CMIT TxIA lost 0/20 psi. in 1st 15 min. and 0/0 psi. in 2nd 15 min. for a total loss of 0/20 psi. in 30 min. test, Final WHp's = 20/20/40 Annulus valves tagged and left open to the gauges at the time of departure. E-Line still on the well 11-07 3/28/2008 ****JOB CONTINUED FROM 27-MARCH-2008****WELL SHUT-IN ON ARRIVAL. T/I/0=90/0/0. E-LINE SET HES 3.65" OD FASDRILL BRIDGE PLUG MID-ELEMENT AT 8778 FT. DEVIATION AT PLUG SET 17 DEGREES. 1 ST PLUG FAILS PT, COULD NOT GET PRESSURE UP PAST 2000 PSI. 2ND ATTEMPT: RIH HES FASDRILL AND SET AT 8775 FT. COMBO MIT PASSES AT 3500 PSI. 4-1/2" TUBING CUT AT 8720 FT WITH 3.65" SCP POWERCUTTER. DEVIATION AT CUT 13 DEGREES. WELL SHUT-IN. FINAL T/I/O: 90/0/0. *'*JOB COMPLETE. *'** 11-07 4/1 /2008 T/I/0= 0/0/0 Temp=S/I Circ-Out (Pre- RWO) Pumped 2 bbls meth spear, 742 bbls 2% KCL down Tbg thru jet cut at 8729' up IA down hard line jumper to flowline of 11-06. *** Job continued on 4-02-08 WSR*** 11-07 4/2/2008 "** Job continued from 4-01-08 WSR*** Circ-Out, CMIT-TxIA PASSED to 3500 psi, MIT-OA PASSED to 2000 psi.(Pre-RWO). Pumped 168 bbls (911 bbls total) 2% KCL down Tbg thru jet cut at 8729' up IA taking returns down hard line jumper to flowline of 11-06. Freeze protected TxIA with 157 bbls diesel down Tbg, U-tubed TxIA for 1 hr. CMIT-TxIA PASSED to 3500 psi. Pressured up TxIA with 7.8 bbls diesel. TxIA lost 60/60 psi in 1st 15 min and 40/40 psi in 2nd 15 min for a total loss of 100/100 psi in 30 min test. MIT-OA PASSED to 2000 psi. Pressured up OA with 2.3 bbls diesel. OA lost 60 psi in 1st 15 min and 40 psi in 2nd 15 min for a total loss of 100 psi in 30 min test. Bled all pressures to 0 psi. Final WHPs 0/0/0 (IA/OA casing valves open to gauges, tags hung, swab shut needle valve open to gauge at time of departure) 11-07 4/7/2008 T/I/0=0/0/0 Set 5" ISA BPV #519 @90"...pre-rig 11-07 4/8/2008 PULL BPV T/I/OA= SI/0/0 Pull 5" ISA BPV for rig prep work. Tagged at 96" with 2' extension. 11-07 4/8/2008 T/I/0=550/200/10, Set 5/1/8" IS-A BPV#259. Set @ 102" set through tree pre rig. 11-07 4/9/2008 T/I/0=0/0/0 Temp=Sl CMIT TxIA PASSED to 4000 psi (Pre RWO) Pumped 11 bbls diesel down Tbg to reach test pressure. TxIA lost 40/40 in the first 15 min.and 10/20 psi second 15 min for a total loss of 50/60 psi in 30 min. FWHP's=0/0/0 Annulus valves tagged & open to gauges. 11-07 4/11/2008 T/I/O = 0/0/0 Set 5 1/8" FMC IS-A BPV Page 1 of 2 http://digitalwellfile.bpweb.bp.coin/WIInfo/Reports/ReportViewer.aspx 5/15/2008 Digital Well File 11-07 4/13/2008 T/I/O = 20/20/0 Pulled 5 1/8" FMC ISA BPV thru BOPE. 11-07 4/19/2008 T/I/0= VAC/0/0; Pulled 4-1/16" CIW "H" TWC thru tree post RWO; 1-2' ext. used tagged @ 96"; ***Complete*** (Best/Wortham) 11-07 4/21/2008 *** WELL SHUT IN ON ARRIVAL***[post rwo] PULLED BALUROD & 4-1/2" RHC PLUG BODY FROM X-NIP @ 8642' MD TAGGED HARD BTM AT 9270' MD W/ 3.50" CENT, S.BLR (SAMPLE OF SCHMOO). ALL PERFS ARE COVERED (PERF INTERVAL 9296' TO 9312'). NOTE; UNABLE LOCATE LOWER WLEG, USED UPPER WLEG FOR CORRECTION. **LEFT WELL S/I, TURNED WELL OVER TO DSO*** 11-07 4/24/2008 *** WELL S/I ON ARRIVAL*** (post rwo) RIH WITH 3.50 CENT,TEL,3.0" LIB TO 9277' SLM. UNABLE TO LOC TT. (IMPRESSION OF A 2.20" OD x 1.70" ID RING). RIH WITH 3.79 CENT TO 8920' SLM. (DID NOT SET DOWN ON 3.725 XN-NIPPLE AT 8798' MD). RIH WITH 4-1/2" X-LINE. UNABLE TO FIND X-NIPPLE AT 8798' MD. APPEARS ORIGINAL TBG TAIL IS NO LONGER PRESENT. *** WELL LEFT S/I. NOTIFY DSO *** 11-07 4/26/2008 T/I/0= 0/60/20 Infectivity Test (MITIA post initial injection post RWO) Temp= SI. Pumped 150 bbls of 60/40 meth at a max rate of 5 BPM. (pumped 178 bbls total for infectivity test) At 85 bbls away tubing pressure leveled out at 1050 psi. thru remainder of test. monitored WHP ,after 30 min.= 0/60/20. MIT-IA PASSED to 2250 psi. Pumped 4.9 bbls of 46* 60/40 Meoh to achieve test pressure. Lost 40 psi / 1st 15 min & 10 psi / 2nd 15 min. Total loss of 50 psi during the 30 minute test. Bled back 4.2 bbls to final WHP= vac/60/0. Annulus casing valves are open to gauges. 11-07 5/3/2008 T/I/0= 620/20/0. Temp=Cold. AOGCC MIT IA PASSED to 2250 psi (Witnessed by L. Grimaldi.) Pumped 5 bbls of meth down IA to reach 2260 psi, IA lost 60 psi in first 15 mins and 10 psi in second 15 mins for a total loss of 70 psi in the 30 min test. Bled -5 bbls. Final Whp's=630/0/0 **Casing valves tagged & open** Print Date: 5/15/2008 Page 1 of 1 Page 2 of 2 http://digitalwellfile.bpweb.bp.com/WIInfo/Reports/RepartViewer.aspx 5/15/2008 11-07i change of scope Sundry 308-090 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, April 14, 2008 2:05 PM To: 'Derrick, George (Mackie) M' Subject: RE: 11-07i (181-177) change of scope Sundry 308-090 Mackie, Thanks for the information. No issue here. I will place a copy of this message in the well file. Tom Maunder, PE AOGCC Page 1 of 1 From: Derrick, George (Mackie) M (mailto:derrgm@BP.com] Sent: Monday, April 14, 2008 1:15 PM To: Maunder, Thomas E (DOA) Subject: 1i-07i change of scope Sundry 308-090 Tom, On well 11-07i the rig was unable to dress off the tubing stub. The dress off tool was freely rotating. It was determined that the k-anchor had released. The plan forward is to pull the k-anchor and tubing stub and then complete the well as planned but setting the packer approximately 75 feet higher then originally planned. This will place the new packer at approximately 8550'. I will keep you updated if we have any other changes. Also please contact me if you need anything else. Thank you for the help. Mackie Mackie Derrick 'v1%c>rk~rve.r Fr:Ginc~er u^ ~xplc;~=ration {r?+t~ska} Inc. derrgm@bp.com ~~~ APR ~ ~ 200 4/14/2008 • • ~~ ~ ~.~ ALASKA OIL A1~TD GAS CO1~T5ERQATIOlUT COM1~II55I011T David Reem Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Wield, Prudhoe Bay Oil Pool, PBU 11-07 ST Sundry Number: 308-090 ~~~ ar~~ ~ zor~~ ~~,1 Dear Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~ Daniel T. Seamount, Jr. Chair DATED this day of April, 2008 Encl. ~ STATE OF ALASKA ~~ A'LA OIL AND GAS CONSERVATION COM ION M~ ~* i~ APPLICATION FOR SUNDRY APPROV~~ ~~ ~ ~~ ,~( ~~~~ 20 AAC 25.280 ,~„~,~.,,~,.,, 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ^ Alter Casing ®Repair Well ~ ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing ~ ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 181-177 3. Address: ®Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029- 8-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: 8. Well Name and Number: ~ ~~'"~~~ PBU 11-07 ST' Spacing Exception Required? ^ Yes ®No ~(( 9. Property Designation: ~- 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028 /-D~ 62' ~ Prudhoe Bay Field / Prudhoe Bay Pool 12. PRESENT WELL COND4TlON SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9472 8986 9428 8945 None None asin Len th Size MD TVD Burst Colla se Structural Conduct r 80' 20" 80' 80' 1490 470 Surface 2659' 13-3/8" 2659' 2659' 5380 2670 Intermediate 8270' 9-5/8" 8270' 7845' 6870 4760 Producti n Liner 1380' 7" 8092' - 9472' 7680' - 8986' 7240 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9296' - 9312' 8820' - 8835' 4-1/2", 12.6# I-80 8811' Packers and SSSV Type: 7" X 4-1/2" TIW'HBBP' Perm Packer Packers and SSSV MD (ft): 8751' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ SOP Sketch ^ Detailed Operations Program ^ Exploratory ^ Development ®Seroice 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: April 25, 2008 ^ Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ®WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mackie Derrick, 564-5891 Printed Na avid Reem Title Engineering Team Leader / Prepared By Name/Number: Signature Phone 564-5743 Date,3~18/D~ Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ,BOP Test .Mechanical Integrity Test ^ Location Clearance Other: " lW~ PS 1 ~0~ ~=ST Subsequent Form Required: "T~ A roved B COMMISSIONER THE COMMISSION Date Form 10-403 Reviseclf 06/2006 Submit In Duplicate 0 R I G I NA L ,-:.~. ~~~ ~ ~Qa~ • . by GPc.P~~nesa~ 11-O7i Rig Workover Scope of Work: Cut & Pull 4-1/2" L-80 completion, change out 9-5/8" casing packoffs, Run new 4-1/2" L- 80 completion. MASP: 2701 psi Well Type: WAG Injector Estimated Start Date: April 25, 2008 Pre-rig prep work: S 1 Drift fora 4-1/2" FasDrill. E 2 Set 4-1/2" Fas Drill @ 8780'. Jet cut in the top of the 1 full joint above the packer 8713'. Ref: 11/4/96 tubin summar F 3 Circulate thru the cut with seawater, CMIT-TxIA to 4000 psi, leave a 2000' diesel freeze protect. Bleed WHP's to 0 psi. W 4 Check the tubing hanger and IC casing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT-T & IC. O 5 Set a BPV in the tubin han er. O 6 Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure: 1. MIRU Nabors 4es. Circulate out freeze protection fluid with sea water through the cut. ND tree. NU and test BOPE to 250 psi low, 4000 psi high. (Annular Preventor to 3500 psi) 2. Pull and LD 4-'I /2" tubing string. 3. Change out 9-:i/8" casing packoffs through the stack. 4. Run new 4-1/2" L-80 premium threaded tubing stacker packer completion with packer at 8625' MD. 5. Displace the IA to packer fluid and set the packer. 6. Test Tubing & IA to 4000 psi. Freeze protect to 2500' MD. 7. Set BPV. ND 13OPE. NU and test tree. RDMO. _- - - TREE = FMC GEN 2 yVELLHEAD= FMC ACTUATOR = AXELSON KB. ELEV = 62' BF. ELEV = ? KOP = 3900' Max Angle = 32 @ 6600' Datum MD = 9343' Datum TV D = 8800' SS (5-1/2" TBG, 17#, L80, .0232 bpf, ~ = 4.892" ~ u 13-3/8" CSG, 72#, L-80, O = 12.347" OF 7" LNR M 8092' 9-5/8" CSG, 47#, L-80, ID = 8.681" ~---~ $274' Minimum ID = 3.725" @ 8798' 4-112" PARKER SWN NIPPLE 28' --~ 5-1 /2" X 4-1 /2" XO, ID = 3.958" 2192' 4-1 /2" CAMCO TRDP SSSV NIP, ID = 3.812" 8100' -~7" X 9-5/8" BAKER LNR PKR 9-5/8" M~LOUT SECTION 8287' - 8334' CEMENT WINDOW 8274' 8692' 4-1/2" PARKER SWS N~, D = 3.813" 8750' 7" X 4-1/2" TNV HBBP PERM PKR, D = 3.960" 8781' 4-1/2" PARKER SWS NIP, ID = 3.813" 8798' ~-~4-1/2" PARKER SWN NIP, ID = 3.725" ~ ~ 4-1/2" TBG, 12.8#, L-80, .0152 bpf, ®= 3.958" PERFORATION SUMMARY REF LOG: BRCS ON 08/06/92 A NGLE AT TOP PERF: 14 ~ 9296' Note: Refer to Productan DB for historical pert data SIZE SPF ~fTERVAL Opn/Sqz DATE 3-1/8" 4 9296 - 9312 0 08/21/92 u 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" DATE REV BY COMMENTS DATE REV BY COMMENTS 2182 ORIGINAL COMPLETION 08!08192 RWO 10/28/01 RNITP CORRECTIONS 05/16/06 RCT/TLH PX PLUG SET 09/29/06 RDW/PJC WANERSAFETY NOTE (8/14/06) 10/13/06 RCT/TLH PX PLUG PULLED 8811' -~4-1/2" WLEG, ID= 3.958" 8813' ELMD TT LOGGED 08/16/92 PRUDHOE BAY UNIT WELL: 11-07 PERMIT No: 1811770 API No: 50-029-20687-00 SEC 33, T11 N, R15E, 744.21 FEL 3588.92 FNL BP Exploration (Alaska) 11 ~~ ~ TES SURE LIMITS IN SOME CASES.CONTACT WIC (x5102) PRIOR TO PRE33URE TESTING *"*TxIA COMM. OPERATING LIMITS: MAX IAP = 2000 PSI, MAX OAP =1000 PSI (08H4/08 WAIVER)'** TREE _ ~ FMC GEN 2 1(VELLHEAD= FMC ACTUATOR = AXELSON KB. ELEV = 62' BF. ELEV = ? KOP = 3900' Max Angle = 32 (dl 6600' Datum MD = 9343' Datum ND= 8800'SS ~ 13-3/8" CSG, 72#, L-80, ID = 12.347" ~ OF 7" LNR ~-{ 8092 11 ~O / ' TES~iESSURE LIMITS IN SOME CASES.CONTACT WIC (x5102) PRIOR TO PRESSURE TESTING "'TxIA Proposed RWO COMM. OPERATING LIMITS: MAX IAP = 2000 PSI, MAX OAP =1000 PSI (08114/08 WAIVER)'" 9-5/8" CSG, 47#, L-80, ID = 8.681" ~ 8274' 9-518" MILLOUT SECTION 8287' - 8334' CEMEPIT WINDOW 8274' Minimum ID = 3.725" ~ 8798' 4-1 /2" PARKER SWN NIPPLE 14-1 /2" X NIPPLE, ID = 3.813" I 8100 ~7" X 9-5/8" BAKER LNR PKR 4-112" X NIPPLE ID = 3.813" 7" x 4-1/2" BAKER S-3 PKR. 4-112" X NIPPLE ID = 3.81 ~" 4-1/2" x 7" UNIQUE GVLr~HUT 8750 7" X 4-1/2" TMJ HBBP PERM PKR, D = 3.960" ~4-1/2" PARKER SWS NIP, ~ = 3.813" ~ 8798' ~~4-1/2" PARKER SWN NIP, ID = 3.725" ~ ~ 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ REF LOG: BHCS ON 08/06/92 ANGLEATTOPPERF: 14 (d 9296' Note: Refer to Productan DB for historical pert data S¢E ~ SPF ~ NVTERVAL ~ Opn/Sqz ~ DATE ~_vR" a o~oa _ 4~~~ n naiwo~ 17" LNR, 26#, L-80, .0383 bpf, ID = 6.276" DATE REV BY COMMENTS DATE REV BY COMMENTS 2182 ORIGINAL COMPLETION 08108192 RWO 10/28/01 RN/TP CORRECTIONS 05/16/06 RCT/TLH PX PLUG SET 09/29/06 RDW/PJC WANERSAFEIY NOTE(8/14!06) 10/13/06 RCT/TLH PX PLUG PULLED 8811' ~4-1/2" WLEG, ID= 3.958" 8813 ELMD TT LOGGED 08/16/92 PRUDHOE BAY UNR WELL: 11-07 PERMrr No: 1811770 API No: 50-029-20687-00 SEC 33, T11 N, R15E, 744.21 FEL 3588.92 FNL BP Exploration (Alaska) 11-07 (PTD #1811770) Internal ~ver Cancellation -Not Operable Well Page 1 of 1 Re James B DOA • 99, ( ) From: Lau, John, Jack [IaujjO@BP.com] on behalf of NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~~ II17I0d~ Sent: Monday, December 31, 2007 7:36 AM '\ To: NSU, ADW Well Operations Supervisor; Rossberg, R Steven; GPB, FS2 DS Ops Lead; GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, Wells Opt Eng; GPB, EOC Specialists; Engel, Harry R; Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Chivvis, Robert; NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech; Lau, John, Jack; Holt, Ryan P (ASRC); Dahlem, Jason E; Culpepper, Jerry K. (Orbis); Boyles, Gerald J Subject: 11-07 (PTD #1811770) Internal Waiver Cancellation -Not Operable Well All, An internal waiver was issued for TxIA communication on water injector 11-07 (PTD #1811770) on 08/14/06. The dispensation from the Well Integrity System Policy for this well aTi s expired. Please ensure the well has been shut-in by the end of today and arrangements have been made to freeze protect the well. -`-°- ` The well has been reclassified as Not Operable. A secure program will be sent shortly. Please remove all Waivered well signs and the laminated copy of the waiver from the wellhouse. A letter requesting cancellation of the corresponding AOGCC Administrative Approval 4E.010 will be signed and mailed this week. .._:... Please call if you have any questions. Thank you, Jack Lau (for Anna Dube) ~I~ ~~~ ~ ~~ ~ODf Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 1/17/2008 . MEMORANDUM TO: r; j/'/JJ'.(! { . ~'J-ti Jim Regg P.l. Supervisor FROM: Bob Noble Petroleum Inspector Well Name: PRUDHOE BAY UNIT 11-07 Insp Num: mitRCN070526083805 ReI Insp Num: Packer Well I 11·07 ¡Type Inj. i N': TVD" ¡ P.T.D¡ 1811770 ¡TypeTest I SPT I Test psi I Interva0EQVAR P/F --;-,,/ Notes: Wednesday, May 30, 2007 . State of Alaska Alaska Oil and Gas Conservation Commission 7 D.\ TE: Wednesday, May 30,2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 11·07 \ <t) \/ \11 PRUDHOE BAY UNIT 11-07 Src: Inspector Reviewed By: P.I. Suprv..::.j¡:~____ Comm NON-CONFIDENTIAL API Well Number: 50-029-20687-00-00 Permit Number: 181-177-0 Inspector Name: Bob Noble Inspection Date: 5/24/2007 Depth Pretest Initial IS Min. 30 Min. 45 Min. 60 Min. ----r---~--~------,---~~--r 8302 I IA , 210 ¡ 2500 ! 2410 ; 2370 ~ I 2500 ! OA; 140 I 300 ¡ 300 I 300 ¡ n_~n~_- -.---'-----------¡---~- ~- . ----~--t-- . -- Tubing i 580 I 670 i 680 I 680 i I "_ _-------'----___1----_.~.._~____ 5CANNED JUN () 6 2007 Page I of I . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor .'--' ¡/d-"ï J) ~i/7 DATE: Thursday, May 24, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) TKC 11·07 PRUDHOE BAY UNIT 11-07 \,..\11 \~ FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: ~r. P.I. Suprv "- . r--- Comm NON-CONFIDENTIAL Permit Number: 181-]77-0 Inspector Name: Jeff Jones Inspection Date: 5/18/2007 Well Name: PRUDHOE BAY UNIT 11-07 Insp Num: mitJJ070519065453 Rei Insp N urn: API Well Number: 50-029-20687-00-00 Packer Depth Pretest Initial ~tW- 11-07 :Type Inj.j, N : T":~ : 830:"_1 IA~n~°-L--.=lO : P.T.D¡ 1811770 ,TypeTest I SPT i Test psi 2075.5! OA l~O_---,---~.!~-1 230 i~ter~~1 REQV'~-P/F-----;- --/ -- Tubing: 70~ ~~~ ! IS Min. 30 Min. 45 Min. 2465 I 2455 I 60 Min. 230 '2860 ----,.- 285()--¡-·----¡---- I ! I --'-~ Notes: This well has known tubing by inner annulus (TxIA) communication and a Tubing tail plug (TTP) was set at 8781' MD to facilitate the combination TxIA MIT. 5.8 BBLS of methanol were pumped. ~JUN 06 20D7 Thursday, May 24, 2007 Page I of I . lVIEMORANDUlVI TO: Jim Regg "-;/K··" /! _I' P.I. Supervisor I é1?; J..!S i: 7 FROM: John Crisp Petroleu m Inspector Well Name: PRUDHOE BAY UNIT 11-07 Insp Num: mitJCr070518111741 ReI Insp Num: Packer Well I 11-07 ,¡'Type Inj. !. N II TVD -,____.L...-....!..___ P.T.D! 1811770 !TypeTest I SPT! Test psi --~--~~._- Interval REQVAR P/F /' P . State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday. May 21. 2007 Sl'BJECT: Mechamcallntegrity Tests BP EXPLORA TlO~ (ALASKA) NC 11-07 PRUDHOE BAY UNIT 11-07 \I{jl- \ 11 Src: Inspector Reviewed By: P.I. Suprv '- Tf3Q.... Comm NON-CONFIDENTIAL API Well Number: 50-029-20687-00-00 Inspector Name: John Crisp Inspection Date: 5/13/2007 Permit Number: 181-177-0 Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 8302TJAT 0 I 0 _u~-;~O-;--~' . ;~755.. 1 OA~ :-.~~o .,. ~~~25;On : ~2450u-~= mo_l-=:2400 -~u~==- 5~/V' Tubing: 180 I ~8~__,-- 180 I 180 : 180 : Notes: Pressure was increased from 2260 to 2500 psi for retest. This weB was going to have CMIT TxIA for variance. I requested Operator to move on to another well & let Supervisors analize data to determine if the well passed or needed retest when CMIT TxIA was performed. Combo test delayed due to WL plug needed to ne set in tubing. ¡I.,\.:P¡ ()~;Z! "7 W!::o4-6'.OiO r<25!i(Ir?§,S Ct-,y"\,,~.u;¡:rcS<A- .:-f CJ.;j;X' 1}i':J:A- Monday, May 21, 2007 5GANJ~ED JUN () 6 2007 Page 1 of I . . MElVIORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor Ké1tl' b¡ -; lJ ? ( !,. DATE: Monday, May 2 J, 2007 SlIBJECT: Mechanical IntegTity Tests BP EXPLOR.ATION (ALASKA) INC II·CJ7 PRCDHOE BAY L'NIT 11-07 \' \'\Î \CO FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv JB?- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT 11-07 Insp Num: mitJCr0705181 I 1210 ReI Insp Num: API Well Number: 50-029-20687-00-00 Permit Number: 181-]77-0 Inspector Name: John Crisp Inspection Date: 5/13/2007 Packer Depth Pretest Initial IS Min. 30 Min. 45 Min. 60 Min. Wcll,------¡¡~07 :Type Inj.i N ¡ TVD : 8302 : IA! ~- 0 I 0 I 0 ; 0 I . ~--~.- " ',' --- \ I - ----------,------- -~~·_--··-----;--_·-~_·--·--l~·--~-------,---~--·----T--··-·----.~,-----_.----- P.T.Di 1811770 iTypeTest ; SPT I Test psi. 2075.5 'OA. 0 I 2500 ì 2400 I 2320 : 2260 I ________~.~_~_-'-----_____.______L_~I_____~. _~.__~------_-,----~-¡.____ _~._ Interval REQVAR _ P/F F . __._ Tubin!l.~~J~_~__:~_~180 I 180 : -- Notes: MIT OA for variance. 2.4 bbls pumped for test Faded due to consistant pressure loss, "/' pJ¡ D!'r~ ,A-:r:-tJ +E ,GID f<?;.(U-I:.e,S ClA;'\l.{¿J!... )...v::rCA- ~ C,t.¡;:w 7)c:::h4- iGANNED JUN 0 6 2007 Monday, May 21,2007 Page I of I . . MEMORANDU~1 State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ~ L-' <} 1,/" \-.j~/FI , v, í ( DATE: Monday, May 2],2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASK-'\) f'iC 11-07 FROM: John Crisp Petroleum Inspector PRUDHOE BAY UNIT 11-07 '1 \C6\~\1 Reviewed By: P.I. Suprv -J13z...-- Comm Src: Inspector Well Name: PRUDHOE BAY UNIT 11-07 Insp Num: mitJCr070518110633 ReI Insp N urn: NON-CONFIDENTIAL API Well Number: 50-029-20687-00-00 Permit Number: 181-177-0 Inspector Name: John Crisp Inspection Date: 5/13/2007 Packer Depth Pretest Initial WclITlí~07 :Type Inj. I NiTVD~--+_~~__.L IA . i -()-~ --L P.T.DI 1811770 ¡TypeTest ! SPT! Test psi 2075.5 I OA I 0 2480 -,--,-~-------,---------~_._----~-----,---------,-",,-- Interval OTHER P/F F IS Min. 30 Min. 45 Min. 60 Min. -.---¡------~ I -- _~_~___~____1______~__~__~__ , Tubing 180 ! 180 I ; ___..1.--_~___L____~_____~__~ Notes: MIT OA for variance.2.4 bbls pumped for test. Had to bleed off pressure before test was finished due to leaking test port 011 surface casing we [ head. -/ .L_,__~_ I /'vCvrðA·2i I /tctl 4é. 0 10 r:7 ! "Xu.. its (t-MlU.<&' J..lYr.:o,'\- f fþlJ::::-¡- ·r~-:¡:..A SCANNED JUN { 6 2007 Monday, May 21, 2007 Page I of I e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Emaílto: Winton _Aubert@admin.slale.ak.us; Bob _Fleckenslein@adin.staIe.ak.us; Jimßegg@admin.slale.ak.us; Tom_Maunder@admin.slate.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), loc. Prudhoe Bay I PBU f OS 11 05113107 Jack Winslow John Crisp \CfJ \ ~ \11 Packer Depth Pretest Initial 15 Min. 30 Min. Well111-07 I Type tnj. I W TVD I 8,302" Tubing 180 180 180 Intervall V P.T.D.11811770 I Typetest I P Test psil 2076 Casing 0 0 0 PIFI F Notes: AOGCC Slate witnessed MIT -OA for variance. OA 0 2480 2380 We1l111-07 I Type Inj. I W I TVD I 8,302' Tubing 180 180 180 180 Intervall V P.T.D.11811770 I Typetest I P I Test psil 2076 Casing 0 0 0 0 PIFI F Notes: AOGCC Slate witnessed MlT -OA for variance. OA 0 2500 2400 2320 Well111-07 I Type Inj. I W I TVD I 8,302" Tubing 180 180 180 180 Intervall V P.T.D.11811770 I Typetest I P I Test psil 2076 Casing 0 0 0 0 PIFI F Notes: AOGCC Slate witnessed MlT -OA for variance. OA 0 2500 2450 2420 Weill I Type Inj.1 TVD I I Tubing I I Interval I P.T.D.I I Type test I I Test psil Casing PIFI Notes: OA I Weill I Type Inj.J J TVD J J Tubingl I Interval P.T.D.I I Type test I I Test psi Casing I PIFI Notes: OA TYPE INJ Codes D ~ Drilling Wasœ G~Gas I ~ Industrial Wastewater N ~ Not Injecting W ~ Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M ~ Annulus Monitoring P ~ Standard Pressure Test R ~ Internal RadíoactNe Tracer SuNeY A ~ Temperature Anomaly Su""'Y D ~ Differential Temperature Test INTERVAL Codes I ~ Initial Test 4 ~ Four Year Cycle V ~ Required by Variance T ~ Test during Workover o ~ Other (describe in notes) ... ''''.-..........- 5iCA;.~ JlIN 1 4 ,007 . '.' .. ..,~,}""",..,_".....,~'^",..It<..-./~i.~' .,.~:' MIT PBU 11-07 05-13-07.xIs Recently approved waiver for 11-07 (PTD #181 1770) . Jim and Winton, Please see the attached waiver for 11-07 (PTD #1811770). «11-07 TxlA PWI Waiver 08-14-06.pdf» If you have any questions, please don't hesitate to call. Thank you, Andrea Hughes (Filling in for Joe Anders) Well Integrity Engineer Office: (907) 659-5102 Pager: (907) 659-5100 x1154 11-07 TxIA PWI Waiver .. 11-07 TxIA PWI Waiver Content-DescnptIOn: 08-14-06.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 9/29/2006 9:09 AM . . Notice of Waivered Well WELL: 11-07 WELL TYPE: Water Injector DATE: 08-14-06 injection Data: 02/12/06: 13,000 bwpd @ 1114 psi. Pressures: Injecting 81 Tubing 860 psi o psi REASON FOR NOTICE: TxlA Communication COMMUNICATION INDICATED BY: · MIT-IA Failed - LLR 3.6 gpm - 05/02106. 9-5/8" ANN 760 o psi psi 13-3/8" ANN 10 psi o psi \\1 / \~\ PRODUCTION CASING INTEGRITY DEMONSTRATED BY: · CMIT-TxIA Passed to 2500 psi - 05/18/06. SURFACE CASING INTEGRITY DEMONSTRATED BY: · MIT-OA passed to 2500 psi - 05/13/06. IMPORTANT CONSIDERATIONS / COMMENTS: · 2 Levels of Protection are the production and surface casings which have been tested to at least 1.2 times the maximum anticipatec injection pressure. · AOGCC issued Administrative Approval AIO 4E.010 dated 07/05/06 for continued water injection only. PLAN OF ACTION: Any deviation from this waiver must be pre-approved by the Wells Group and the Operations Manager. · Allow PWI injection - no MI injection allowed. · Tubing and IA pressures may equalize. · Monitor well head pressures and log daily. · Submit a monthly report of injection rate and wellhead pressures to the AOGCC. · Perform the following waiver compliance testing: . Annually conduct a CMIT-TxIA to at least 1.2x maximum injection pressure. . Annually conduct a MIT-OA to at least 1.2x maximum injection pressure. · Stop injection and notify the AOGCC upon indication of compromised integrity. Operating Limits Max lAP = 2000 psi Max OAP = 1000 psi }lnna q)u6e I am approving this document 2006.08.1421 :04:56 - 08'00' Well Integrity Coordinator Date ¡, Digitally signed by Olsen, Clark A '[ DN: CN ~ Olsen, Clark A 1\,Reason: I am approving this i J109!'m!''nt . ' Date:2006.0B.15 05:24:35 -OB'OO' Olsen, Clark A Well Operations Supervisor Date H E I f RI' Digitally signed by Herry Engel for R. arry nge or 11 Steven Rossberg ß¡ ON: CN = Harry Engel for R. Steven Steven Rossberg.· "'~oSSberg. . C = US, ou = Alaska Drilling & ..Weut;· / Reasotf:'· I am approvìng this document Dale: 2006.0B.1510:41:2B -OB'OO' Well Operations Manager Date Operations Manager Date Distribution: DS I Pad Operator OS I Pad Engineer WOE Walker, Robert N / Digitally signed by Walker, Robert N N: CN = Walker, Robert N 006.09.1206:12:06 - 08'00' Area Manager Date ¡. Digitally signed by Kurz, John J 0 h I1v ON: CN = Kurz, John, OU = Client i'\~eason: I am approving this . .doeu:rnent Date: ~006.09.12 10:36:51 -OB'OO' { ,- Kurz, ~T~v~t ~-71aL1 ®~ ~liil~r~a~~7y ®i~e79~~~~~a~A~ ~~~s7~~1~ • FRArIIOC 6~1. MURfCOWSICI, GOVERAlOR 333 W 7"" AVENUE, SUITE 100 ANCHORAGE, ALASKA 9950?-3539 PHONE (90T 279-1433 FAX (907) 276-7542 ADMI'_~;ISTR~TI~"E APPROVAL AIO ~E.010 :LIr. Steve Rossberg Wells Manager BP Exploration (Alaska) Inc. 90Q East Benson Blvd. P O. Box 196612 Anchorage, AK 99~ 19-6612 RE: PBU 11-07 (PTD 18 I-177) Request for Administrative Approval Dear Mr. Rossberg: In accordance with Rule 9 of Area Injection Order ("AIO") O~E.000, the Alaska Oil and Gas Conservation Commission (~`AOGCC" or "Commission") hereby grants BP Exploration (Alaska) Inc. ("BPXA'')'s request for administrative approval to continue water injection in the subject well. AOGCC finds that BPX.~ has elected to perform no corrective action at this time on PBU 11-07. The Commission further finds that, based upon reported results of BPXA's diagnostic procedures, PBU 11-47 exhibits two competent barriers to release of well pressure. Accordingly, the Commission believes that the w-ell's condition does not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's administrative approval to continue water injection in PBU 11-07 is conditioned upon the following: I. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injection rates; 3. BPXA shall perform an annual tifIT - OA to 1.2 times the maximum anticipated well pressure, the anniversary date of which shall be this approval's effective date; ~. BPXA shall perform an annual Cti1IT - T x IA to 1.2 times the maximum anticipated well pressure, the anniversary date of which shall be this approval's effective date; AIO 4E.0 (0 July ~, ZOQ6 Page 2 at 2 ~. BPXA shall Limit the well's OA pressure to 1000 psi; 6. BPXA shall immediately shut in the well and notify the AOGCC if therein any change in the well's mechanical condition; and ?. after well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection. Please note that PBU 11-07's status remains 1 VJINJ. As provided in AS 31.0.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may File with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4 ~ 0 PLt on the 23rd day following the date of this letter, or the next working day if the 2~rd day falls on a holiday or weekend. A person may not appeal. Commission decision to Superior Court unless rehearing has been requested. ~~ Alaska and dated July ~; 2006. 0 or an Daniel T. Seamount, Jr ~:..._.,,., Commissioner ,~ ; - ,-. ,, -Cathy;~P. Foerster Commissioner STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.slale.ak.us OPERA TOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay I PBU I DS 11 OS/24/06 Anna Dube .-'j "7¡ Packer Depth Pretest Initial 15Min. 30 Min. We1l111-0B I Type Inj. I N TVD I 8,086' Tubing 200 2,550 2,550 2,550 Interval I V P .TD.11842290 I Type test I P Test psi I 2021 Casing 100 2,550 2,550 2,550 P/FI P Notes: CMIT-TxIA to 2500 psi for waiver compliance OA 0 0 0 0 AOGCC Rep John Crisp declined to witness /' We1l111-07 I Type Inj. I N I TVD I 8,302' Tubing 2,640 2,640 2,640 Interval I V P.T.D.11811770 I Typetest I P I Test psi I 2075 Casing 2,500 2,480 2,470 P/FI P Notes: CMIT - TxlA 10 2500 psi for new waiver OA 0 530 540 540 AOGCC Rep John Crisp declined to witness Weill I Type Inj.1 I TVD I Tubing I Interval I P.TD.I I Type test I I Test psil Casing I I P/FI Notes: OAI I Weill I Type Inj.1 ì TVD I Tubing Interval I p.T.D.1 I Type testl ì TestpsiT Casing P/FI Notes: OA Weill I Type Inj.1 TVD T Tubing ì I ì Interval I P.T.DI I Type test I Test psiT Casing P/FI Notes: OA ì TYPE INJ Codes D = Drilling Waste G = Gas ! ::: Industrial Wastewater N = Not Injecting W = Water TYPE TEST Codes M ::: Annulus Monitoring P = Standard Pressure Test R::: Internal Radioactive Tracer Survey A = Temperature Anomaly SUNey 0::: Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V::: Required by Variance T::: Test during Workover 0= Other (describe in notes) MIT Report Form BFl 9/1/05 MIT PBU 11-08 & 11-07 05-24-06-1.xls RE: 11-07 Possible TxIA Comm lðJ. JiÎ Hello Jim, Bob and Winton. Injection well 11-07 failed an MITIA on 5/2/06. The IA was pressured to 2500 psi, IA pressure decreased 1000 psi in 15 minutes. The well is currently on injection. Plan forward is as follows: 1. Add to the monthly UIC report 2. DHD: Liquid No-Flow Test -IA 3. SL: Set TTP 4. FB: CMIT TxlA to 3000 psi, MITOA to 3000 psi 5. WIE: Eval for AA , ~. - {,¡: ~.V n ç: (If¡fù:, 'G,;;;.:. .¡....."'.iAÌì\o.'iiìo..~~ :;1'1:, V,1 I,", c..U...l: U'WI'D~D'1~tj ~h"''' ~ v Attached is an MIT form. Please call with any questions or if you would prefer some other evaluation approach. Joe 659-5102 «MIT PBU 11-07 05-02-06.xls» From: Anders, Joe l Sent: Monday, May 01, 2006 10:55 AM To: Jim_Regg Uim_regg@admin.state.ak.us); AOGCC - Winton Aubert (winton_aubert@admin.state.ak.us) Cc: Hughes, Andrea; Byars, Scott K (VECO); MCCOllUM, CODY 0 (VECO); Cooper, Katrina N; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, FS2/COTU Area Mgr; Shearer, Daniel (ASRC ENERGY SERVICES); Saunders, Gideon; NSU, ADW Well Integrity Engineer; GPB, FS2 DS Ops lead Subject: 11-07 Possible TxIA Comm Hi Winton & Jim. Well 11-07 (PTD 1811770) is exhibiting signs of TxlA communication. The IA pressure recently increased to the tubing pressure. We bled the IA pressure and it re-pressured 300 psi in 30 minutes. Current plans are to conduct an MITIA. We will inform you of the results. Attached is a wellbore schematic and TIO plot. Please call with any questions. lof2 5/4/2006 8:46 AM RE: 11-07 Possible TxIA Comm e e Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100,x1154 Email: NSUADWWelllntegrityEngineer@bp.com PBU 11-07 Content-Description: MIT PBU 11-07 05-02-06.xls Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 20f2 5/4/2006 8:46 AM e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test e .? .\~ \0 (p /'~--e. rJ ~yy Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay I PBU I DS 11 05/02/06 Joe Anders Packer Depth Pretest Initial 15 Min. 30 Min. We1l111-07 I Type Inj. I W TVD I 8,302' Tubing 800 800 825 Interval I 0 p.T.D.11811770 I Typetest I P Test psil 2076 Casing 720 2,500 1,500 P/FI F Notes: MITIA Failed, lost 1000 psi in 15 minutes OA 0 0 0 Weill Type Inj. I I TVD I I Tubing Interval P.T.D.I I Type test I I Test psi! I Casing P¡FI Notes: I OA Weill I Type Inj. I TVD I I Tubingl Interval I p.T.D.1 I Type test I I Test psil I Casing P¡FI Notes: I OAI Weill I Type Inj.1 I TVD I I Tubing I I I Interval I P.T.D.I I Type test I I Test psil Casing P¡FI Notes: I OAI Weill I Type Inj.1 I TVD I Tubingl Interval P.T.D.I I Type test I I Test psil Casing I P¡Fl Notes: OAI TYPE INJ Codes D = Drilling Waist G = Gas I = Industrial Waistewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) MIT PBU 11·07 05-02·06.xls 1REE= WELLHEAD = AClUATOR= KB. ELEV - BF. ELEV - KOP= MaxA le= !:alum ~ = !:alumlVO= FWC GEN 2 FWC AXELSON 62' ? 3900' 6600' 9343' 8800' SS 5-112" TBG, 17#, L80, 0.0232 bpf, 10= 4.892" TOP OF 4-1/2" TBG I D\TE 2182 08108/92 01110101 02102101 10/28/01 13-3/8" CSG, 72#, L-80, 10= 12.347" 8092' 19-5/8" CSG, 47#, L-BO, 10 = 8.681" I 8274' Minimum 10 = 3.725" @ 8798' 4-1/2" PARKER SWN NIPPLE 14-112" TBG, 12.6#, L-BO, 0.0152 bpf, 10= 3.958" 1 11-07 . 8811' 7" LNR, 26#, L-80, 0.0383 bpf, 10 = 6.276" REV BY COMNENTS o RIG INA L COMA.. EllON RWO SIS-MNH CONVERTED TO CANVAS SIS-LG REVISION RNIlP CORRECllONS DATE REV BY COMNENTS e SAFETY NOTES: FHLIllW HBBP A<RSHAVEREDUCEO TEST PRESSURE Llms IN SOME CA SES. CONTACT ACE (x5102) PRIOR TO PRESSURE TESllNG. 28' 5-112"X 4-112" XO, 10=3.958" 2192' -14-1/2" CAWCOTRDPSSSV NIP, 10- 3.812" 8100' 7" X 9-518" BAKER LNR PKR 9-518" MLLOUT SECTION 8287' - 8334' CEMENTWIt\ÐOW8274' 8692' 4-112" PARKER SWS NP, 10 - 3.813" 8750' 7" X 4-112" T1W HBBP ÆRM PKR, 10 - 3.960" 8781' -14-1/2" PARKERSWS NIP, 0=3.813" I 8798' 4-112" PARKER SWN NIp, 10= 3.725" 8811' 8813' -14-112" VllLEG, 0-3.958" 1--1 ELMO TT LOGGED 08/16/92 9430' 9472' PRUDHOE BAY UNrr WELL: 11-07 PERm f\b: 1811770 API f\b: 50-029-20687-00 SEC 33, T11N, R15E, 744.21 FEL 3588.92 FNL BP Exploration (Alaska) ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Q. q JI{O~ ' \e4C( ("fb Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.uS;Jim_Regg@admin.state.ak.us;TomMa.nder@admin.state.ak.us OPERATOR: BP Exploration (Alaska) Inc. g" I --- ---- FIELD I UNIT I PAD: Prudhoe Bay / PBU / DS-11 ~ DATE: 09/02/05 OPERATOR REP: Donald Reeves AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. well 11-07 I Type Inj. S TVD I 8,302' Tubing 1,100 1,120 1,120 1,120 Interval 4 P.T.D. 1811770 Type test P Test psi 2500 Casing 0 2,500 2,460 2,445 P/F P Notes: 5 bbls 60/40 meth OA o 0 0 0 well 11-29 I Type Inj. S I TVD I 8,302' Tubing 950 950 950 950 Interval 0 P.T.D. 1940520 Type test P Test psi 2500 Casing 900 2,500 2,470 2,470 P/F P Notes: Annual MITIA for waiver compliance. OA 240 320 320 320 1 bbl 60/40 meth well 11-29 I Type Inj. S I T:~PSil 8,302' Tubing 950 950 950 950 Interval 0 P.T.D. 1940520 Type test 2400 Casing 440 740 770 800 P/F P Notes: Annual MITOA for waiver compliance. OA 220 2400 2310 2275 3 bbls diesel weill I Type Inj. I TVD I Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA weill Type Inj. I TVD I Tubing Interval P.TD. Type test T est psi Casing P/F Notes: OA TYPE INJ Codes D = Drilling Waist G = Gas I = Industrial Waistewater N = Not Injecting W = Watèr TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) ~C^NNEO NO\~ Ü ~ 2.0U~1 MIT Report Form BFL 9/1/05 MIT PBU OS-11 9·2-05.xls ilJ4A- (I cr/2-ooJ./ STATE OF ALASKA r;---r..J II c¡ I ({ ALASKA OIL AND GAS CONSERVATION COMMISSION ~ It (~ I APPLICATION FOR SUN DRY APPROVAL 20 AAC 25.280 1. Type of Request: D Suspend D Operation Shutdown D Perforate 0 WaiverD Annular Disposal 0 Abandon Alter Casinq 0 Repair Well 0 Pluq Perforations D StimulateOO / Time Extension 0 OtherD Change Approved Program D Pull Tubing 0 Perforate New Pool D Re-enter Suspended Well 0 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. 181-1770 /' Development D Exploratory D 3. Address: P.O. Box 196612 6. API Number ./ Anchorage, Ak 99519-6612 Stratigraphic D Service Œ1 50-029-20687 -00-00 7. KB Elevation (ft): 9. Well Name and Num~ 62.00 KB 11-07 8. Property Designation: 10. Field/Pool(s): \ ADL-0028325 Prudhoe Bay Field I Prudhoe Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (md): Junk (md): 9472 8986.2 9430 8884.4 None None Casing Length Size MD TVD Burst Collapse top bottom top bottom Conductor 80 20" 91.5# H-40 35 - 115 35.0 - 115.0 1490 470 Liner 1380 7" 26# L-80 8092 - 9472 7679.5 - 8986.2 7240 5410 Production 7488 9-5/8" 47# L-80 33 - 7521 33.0 - 7159.3 6870 4760 Production 1908 9-5/8" 47# SOO-95 7521 - 9429 7159.3 - 8945.5 8150 5080 Surface 2625 13-3/8" 72# L-80 34 - 2659 34.0 - 2658.7 4930 2670 Perforation Depth MD (ft): I Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9296 - 9312 8820 M 8834.7 4.5 " 12.6 # L-80 28 - 8811 5.5" 17# L-80 25 - 28 Packers and SSSV Type: Packers and SSSV MD (ft): 4-1/2" Camco TRDP SSV 2192 4-1/2" TIW HBBP-R Packer 8751 7" Liner Top Packer 8100 12. Attachments: Description Summary of Proposal D 13. Well Class after proposed work: Detailed Operations Program ŒJ BOP Sketch D ExploratoryD DevelopmentD Service ŒI <" 14. Estimated Date for February 1, 2004 15. Well Status after proposed work: Commencinq Operation: OilD GasO PluggedO Abandoned D 16. Verbal Approval: Date: WAGD GINJD WINJŒ] WDSPLD Commission Representative: Prepared by Garry Catron 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Babcock Printed Name Dan Babcock Title Petroleum Engineer Signature ~~ Phone 564-5735 1nl04 Commission Use Only tiunary Number: Conditions of approval: Notify Commission so that a representative may witness R.~ C E !\!~..!JOy Plug Integrity 0 BOP TestO Mechanciallntegrity Test D Location Clearance 0 JAN 0 8 2004 Other: Alaska Oil & Gas Cons. Commission 10-- Va,! Subsequent Form Required: Anchorape ) Original Signed"Sy BY ORDER OF Date: \ I~ /)L} Approved by: Sarah Palin THE COMMISSION I ~)(;~~MEtD JAN ], ¿1 2004 ORIG\NAL ~Bfl .1:3 20{M Form 10-403 Revised 12/2003 SUBMIT IN DUPLICATE bp ... "".",. ........~ ~.... ~..- --:..- ...~ .¡:...-. .'I'~~I\~ ". To: John Smart/Doug Cismoski GPB Well Ops Team Leaders Date: 1/05/04 From: Kristin Carpenter Jennifer Julian Engineer Senior Design Engineer Subject: OS 11-07 Mud Acid Stimulation PBLO11007 Cap Sus Est. Cost: $75M lOR: 200 Please drift, perlorm SBG, aria- rform a mud acid stimulation in injector 11-07i. 1. 0 ../Schmoo-be-gon See recipe in procedure if needed. . 2. S C PuJ,I.~§.- necessary. Drift and tag. 3. C -FCO w/Mud acid stimulation. (Test separator NOT required) Current Status: Deviation: Min. 10: Last TO tag: Last DH Ops: Latest H2S value: Produced Water Injector. Current injection is 1091 BWPD @ 1736 psi /' 32 degrees @ 6600'. Perl deviation is 14 degrees @ 9296'. 3.725" @ 8798' 4-1/2" Parker SWN Nipple 12-15-96 FCO to 9350' 3-18-97 Pull TTP @ 8798'MD ( Beware of the potential for H2S in the returns.' Well 11-07i is an injector completed in zone 1. The well is twinned with 11-08i. As recently as August this well was injecting on the order of 8000 BWPD. It has dropped in the last. couple weeks to merely 1000 BWPD at similar injecijon pressures. The purpose of this program is to reestablish injection in well 11-07i. / Contact Jennifer Julian at x5663, 274-0929 (home) or 240-8037 (cell) with any questions or comments. cc: w/a: Well File D. Babcock J. Julian K. Carpenter w/o a: S. Rossberg 1 11-07i CT Mud Acid Program Prepared By: Kristin Carpenter Jennifer Julian Phone#: 564-5663 (w), 274-0929 (h), 240-8037 (c) JOB PLANNING DETAILS: Perfs: 9296-9312' MD 16' interval Perf Deviation: 14° @ 9296'. Gas Lift Design: N/A. Last MITIA passed 9/16/01. 3/18/97 Fish plug at 8798'. 12/15/96 FCC to 9350'. TD Tag History: Injectivity: 1091 BWPD (0.76 BPM) at 1736 psi 12-15-03 Displacement bbls: 152 bbls (tubing = 134, liner to top perf = 18) Static: 3537 psi 7/29/95 PFtI$P;:WQI;:ÎI<::,;,.. .~ '..... " .. .... ..,.. . ".. ..' ..,."...,' .. 1. Perform a Schmoo-Be-Gone treatment to remove schmoo from the tubin . Mix Volumes reatment Volumes SBG Dis ersant 75% SBG Dis ersant Well DS11- 07i 154 154 26 1100 128 154 116 2. Pull SSSV if necessary. Drift the tubing as deep as possible to ensure there are no obstructions. ".6'.'.."-':... .'O'...".p'...'..e'..'.'.R".. .tt.'..rr..'..I..O......'N..'...S.. "...".... .... . . . . . ... . ... ..'. ."......,'........',., ... .:L.. .,..'.....,'.... .': ..., . ,.,......,. ..',. .' .". ,. . ..'.. .', ..... .', ,'... . '...'.' ...' ...... ".. .". " ."... ... 3. MIRU CT. RU return line to adjacent well or returns tank. Trap 1000 psi on the IA to ensure packer does not unseat during job. Be aware of the potential for H2S in the returns. 4. MU side jetting nozzle (Min completion ID = 3.725"). Jet the tubing at maximum rate with slick, filtered 150°F water while RIH as slowly as is practical. Take returns at surface. 5. Continue to jet the liner to PBTD. Last FCC got to 9350'. 2 6. Circulate bottoms up while reciprocating the coil across the liner up to the tubing tail at 8811' MD. 7. Pull above the top perfs and check for injectivity down coil with a maximum WHP of 2000 psi. 8. Make multiple passes across the perfs and pump the following at maximum rate with a recommended maximum WHP of 2000 psi. Make one pass to bottom while pumping the overflush. Don't POOH until the entire overflush has been pumped behind pipe in order to reduce the chance of stirring up schmoo. 25 bbls 3% NH4CI with 10% U-66 and 0.2% F103 / 50 bbls 7.5% HCI 50 bbls 9% - 1 % HCI-HF 100 bbls 3% NH4CI with 10% U-66 and 0.2% F103 overflush (behind pipe) Please note the initial and final injectivity in the WSR summary. Please note the rates and pressures in the WSR when each stage hits the perfs. 9. POOH. Bleed lAP. ROMO. Immediately put on injection. Treatment Design: . ....125 bbls 3% NH4CI water with 10% U-66 and 0.2% F103 / 50 bbls 7.5% HCI 0.5% A261 0.5% A201 20 ppt L58 0.2% F103 0.5% W54 0.5% W35 50 bbls 9/1 HCI/HF 0.5% A261 0.5% A201 20 ppt L58 0.2% F103 0.5% W54 0.5% W35 Please note the acid titrations and iron ppm on the WSR. 3 lREE ".. FWC GEN 2 WELLHEAD = FWC ACTUATOR = AXB...SON KB. B...BI = 62' BF. B...BI = ? KOP = 3900' f'Jax A Ie = 6600' D3tum fvI) = 9343' D3tum lV D = 8800' SS 5-1(2" lBG, 17#, L80, 0.0232 bpf, ID = 4.892" TOP OF 4-1/2"lBG 28' 28' 13-3/8" CSG, 72#, L-80, ID = 12.347" 2659' TOP OF 7' LNR 8092' 19-5/8" CSG, 47#, L-80, ID = 8.681" I 8274' Minimum 10 = 3.725" @ 8798' 4-1/2" PARKER SWN NIPPLE 4-1/2"lBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" 11-07 / SAFErY NOlES: FI-LIT1W H3BP A<RS HAVE REDUCED TEST PRESSURE LlMTS IN SOME CA SES. CONTACT ACE (x5102) PRIOR TO PRESSURE TESllNG. 28' 2192' 5-1/2" X 4-1/'Z' XO, ID = 3.958" 4-1/2" CAWCOTRDPSSSV NIP, ID= 3.81'Z' 8 8100' 7" X 9-5/8" BAKER LNR PKR 9-5/8" MLLOUT SECTION 8287 - 8334' CEM8\lTWINDOW 8274' 8692' 4-1/2" PARKER SWS NP, ID = 3.813" -17" X 4-1(2" 1lW HBBP ÆRM PKR, ID = 3.960" 8750' 8781' -i4-1/2" PARKERSWS NIP, D =3.813" I 8798' 4-1/2" PARKER SWN NIP, ID = 3.725" 8811' 8811' 8813' -14-1(2" WLEG, D = 3.958" I I~ B...MD TT LOGGED 08/16/92 I 9430' 7" LNR, 26#, L-80, 0.0383 bpf, ID = 6.276" 9472' DATE REV BY COMMENTS DATE REV BY 00 MrvENTS 2/82 ORIGINAL COMR...EllON 08/08/92 RWO 01/10/01 SIS-fvMIH CONVERlED TO CANV AS 02102101 SIS-LG RBIISION 10/28/01 RN/lP CORRECllO NS PRUDHOE BAY IJ\JIT WELL: 11-07 PERMIT f\b: 1811770 API f\b: 50-029-20687-00 SEC 33, T11 N, R15E, 744.21 FEL 3588.92 FNL BP Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ SCHMOO-B-GONE Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development_ RKB 62 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__X Prudhoe Bay Unit 4. Location of well at surface 8. Well number 253' FNL, 81' FEL, Sec. 33, T11N, R15E, UM (asp's 707479, 5951470) 11-07 At top of productive interval 9. Permit number / approval number 3979' FNL, 856' FEL, Sec. 28, T11 N, R15E, UM (asp's 706658, 5953002) ~4 181-177 At effective depth 10. APl number 3602' FNL, 754' FEL, Sec. 28, T11N, R15E, UM (asp's 706749, 5953381) % 50-029-20687-00 At total depth 11. Field / Pool 3592' FNL, 746' FEL, Sec. 28, T11 N, R15E, UM (asp's 706757, 5953392) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 9472 feet Plugs (measured) true vertical 8986 feet Effective depth: measured 9430 feet Junk (measured) true vertical 8946 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 80' 20" 275 Permafrost II 116' 116' 2700 sx Fondu & 400 sx Surface 2623' 13-3/8" 2659' 2659' Permafrost Intermediate 8238' 9-5/8" 788 sx Class 'G' 8274' 7850' Liner 1380' 7" 8092' - 9472' 7680' - 8986' Perforation depth: measured Open Peres 9296'- 9312' ,~J~,~ 3 ~ ~.003 true vertical Open Peres 8820' - 8835' ~8,S~8.0[[ & [~aS (;ODS, ~0~[t'(tS,~t0Q Anchorage Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, Tubing @ 28'. 5-1/2" x 4-1/2" XO @ 28'. 4-1/2", 12.6# L-80, Tubing @ 8811'. Packers & SSSV (type & measured depth) 7" x 9-5/8" Baker Liner Packer @ 8100'. 7" x 4-1/2" TIW HBBP Perm Packer @ 8750'. 4-1/2" Camco TRDP SSSV Nipple @ 2192'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 11/10/2002 10414 1714 Subsequent to operation 01/02/2003 ~0~'11~1~'~ ~'~ ~ ~ 2003 1876 15. Attachments 16. Status of well classification as: ,=,~.~¢-~ ,~,,--~.,~ Copies of Logs and Surveys run _ Daily Report of Well Operations __ Oil __ Gas __ Suspended __ Service WATER INJECTION 17. I hereby certify that the foregoi_ng is~t~rue~nd correct to the best of my knowledge,_ ,~,,~ ~.-~ .~ ~3--~ Title: Techical Assistant Date January 03, 2003 DeWayne R Schn Prepared by DeWayne R Schnorr 564-5174 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 11/15/2002 01/02/03 11/15/02 01/02/03 11-07 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS SCMOO-B-GONE--SBG: SCMOO-B-GONE TESTEVENT--- TN]ECTTON PRESSURE, PST: 1,876: 8,860 BWPD. EVENT SUMMARY PERFORMED SCHMOO-B-GONE TREATMENT. TESTEVENT--- INJECTION PRESSURE, PSI: 1,876: 8,860 BWPD. TYPE: PW VOLUME: TYPE: PW VOLUME: FLUIDS PUMPED BBLS 15 NEAT METHANOL 154 SCHMOO-B-GONE MIX 115 SEA WATER 284 TOTAL SCANNED FEB 0 A 2003 Page I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy O Taylor L~ DATE: September 16, 2001 Chairman \_ THRU: Tom Maunder SUBJECT: Mechanical Integrity Tests P.I. Supervisor DS 11 ~' 11-7 FROM: Chuck Scheve PBU Petroleum Inspector Prudhoe Bay NON,- CONFIDE .NTIAL Packer Depth . Pretest Initial, 15 Min. 30 Min.. w,~q11-7 ITypelnj-I s I T.V.D. I 83o2 I'fUb~rml 21001 2100 i 2100 I. 2100 P. TiDil:lSl'1:~'iT.ypetestl 'P, ITeStpsil 2076 I ca,~l ~oo ,I 247,01 24501 24401 P/F go~: 4-year , ,w,,l p.T.D.I ', w,,,! P.T.D.I , P.,T.D.I ,, Holes: w~l ~;~.1 IType'ni-t' IT'-v-D- I I Tubirml ' II I ' I'"t'~"'"l I,T~ ,re,ti ', I'T~I , I ~s~l ' I I ,, I ,, ,I P/F '1' IT~'ni-I IT-v-D-"I ' ' I' Tubi~'l' ' 'I ' I ' I "'l'"terva~'l" ',,I,Ty~te~tl ' . ITestp~il ' Ic=s~"gl... '1 I I'..!. P/F i IT,-''"~-I ' I ~.V.D: ! I Yu,~"~l '1 I 'i'' '/'"'~1" , ITypetestl IT~psil .... I cas~.g'l ' I"I''1. ! P/F ,I ' . I Txpe'"'~'l ' I~'v'~)' i ITubi";! "1 !'I ' ' I'"t"v~"l" IT'/Petestl . I.Test PSi'l . . . i Casi'm I ' I. ' i I.. I P/F I Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to BPXs Drill Site 11 and witnessed the 4 year MIT on well 11-7. The pretest tubing and casing pressures were observed and found to be stable. The casing was then pressured up and observed for 30 minutes with the well demonstrating good mechanical integrity. M.I.T.'s performed: l_ Attachments: Number of Failures: g Total Time during tests: 1, hour CC: MIT report form 5/12/00 L.G. MIT PBU 11-7 9-16-01 CS.xls 10/1/01 ARCO Alaska, Inc. Date: Subject: From/Location: Telephone: To/Location: r P.O. Box 100360,(.,tchorage, AK , - Mar 15,' 1994 Transmittal #: 94029 0( John E. DoGrey/ATO-1529 (907) 263-4310 Distribution iWell i Log Date Tool Type Run, Contractor NumberI (M-D-Y) Scale i~t ~ 01-02 f 2-26-94 Prod/Spin/Templ!~.,.,~ 1, 5" Schlumber t[~ ~ 01-03I 2-19-94 Prod/~BSFFemp~ .~'J 1, 5" Schlumber ~, { 01-09 ! 3-01-94 Tubin(:j Cutter ~.> 1, 5" Schlumber ~3- 01-11I 2-27-94 Prod Prof/Spin 1, 5" Schlumber 7..c~ 01-18 2-23-94 Leak Detection 1, l"& 5" Schlumber ~b'5 01-25 I 3-06-94 CNLI 1, 5" Schlumber q"~ ~)3-20A 2-17-94 Perf ~ 1, 5" Schlumber ~03-20Ai 3-03-94 Dual Burst "~'~:!~' 1, 5" Schlumber ~,13~ 03-32 2-26-94 Leak/Press/Temp 1, 2" Schlumber [e~ 03-34A I 2-24-94 Prod/Press/Tamp 1, 2"&5" Schlumber ql. 04-01~ 2-19-94 Prod 1, 5" Schlumber ~* 04-24 ! 2-22-94 Prod 1, 5" Schlumber I~ l 04-40I 2-22-94 Perf 1, 5" Schlumber ~_~"'~ f 04-46 I 2-16-94 Rope Perf 1, 5" Schlumber t~ /04-47I 2-18-94 v, Perf 1, 5" Schlumber ,.04-47 '2-15-94 '." CBT-GR 1, 5" Schlumber X,04'47 i 2-15-94 v CET-GR 1,5" Schlumber 50 05-06 2-11-94 Perf 1, 5" Schlumber ~ 05-14A 7-11-93 USIT/Cem&Corr (~"~1, 5" Schlumber cl°r i 05.15A 05-15A cC~ C.:~ID/GR-L.w~> ~ 1, 5" Schlumber [t'~I 05-26 3-02-94 Dual Burst 161 ? 1, 5" Schlumber ~?.. '/'06-15 2-21-94 Prod 1, 5" Schlumber \ 06-15 2-22-94 Comp Neutron 1, 5" Schlumber 5'~ 06-22A 3-01-94 Perf 1, 5" Schlumber Ilo 07-08 3-02-94 Prod/~~ 1, 5" Schlumber 07-23 3-07-94 Leak/Spin/Temp/~!~ 1, 5" Schlumber 09-34 2-21-94 Tubin9 Cutter ~ '1, 5" Schlumber .t"/-~ 11-02 2-10-94 Inj Pmf/~'~ ~f~, 5" Schlumber ~E) /'11-04 2-20-94 Tubin9 Cutter t~ 1, 5" Schlumber ~11-04 2-17-94 Tubing {:'~,~,.y. ~ Cv..1, 5" Schlumber t"+~ 11-7ST 3-06-94 Inj Pmf/Spin J~l~51t',~-- 1, 5" Schlumber 11- I 2-25-94 Leak/Press/Tamp 1, 1"&5" Schlumber ~ 16ST /Spin//~b ~--I.~ "~111'i 3-08-94 Comp/l~l~,table 1, 5" Schlumber 6ST I ZOCO--- IZ~ ~ .O m /11-17 i .2-20-94 Leak 1,5" Schlumber 1-17 f 3-08-94 Prod 1, 5" Schlumber ti% 11-23i 8-09-91 TMD 1, 5" Halliburton 7.DL~ /11-24A. 3-05-94 Perf/GR/CCL 1, 5" Schlumber ~! 1-24A t 2-22-94 Comp/Perf 1, 5" Schlumber ARCO Alaska, Inc. la a 8ubal~lary of AtlantlcRlehtleldCompmly 12-01 i 3-06-94 I Prod I 1, 1"&5" Schlumber 13-10 f 2-24-94I Perf i 1 5" Schlumber t 14-2B 1-16-94 CNL./GR i 1, 2"&5", Schlumber 14-2B 1 16-94 I Sub-Sea i 1, 1"&2" Schlumber 14-2B i 1-16-941 BH~Acoustilo~]/~¢-l, 2"&5" Schlumber f 14-2B i 1-16-94 Dual Latedo~GR(~:~ 1, 5" Schlumber 14-2B 1-19-94 Se~j Bond/GR(cC~, 1, 5" Schlumber 14-2B 1-23-94 PFC/GR/CCL i 1, 5" Schlumber .14-2B 1-23-94 PFC/Collar i 1, 5" Schlumber 14-24 2-19-94 Leall( I 1, 5" Schlumber 14-28 3-05-94 Leak i 1, 1"&5" Schlumber 14-34 2-15-94 Prod/Press/Temp I 1, 2"&5" Schlumber 16-08 3-07-94 Prod Prof/Spin I 1, 2"&5" Schlumber 17-21 2-24-94 Perf I 1, 2"&5" Schlumber PWDW 2-09-94 Water ~ 1, 5" Schlumber 02-01 Inj/FBS/Templ¢.~ ..... ~5'Z.-: * Well 4-24 the correct AP! # is 50-029-21508-00 Number of Records: Distribution: Central Files Phillips Chevron ANO-8 Geology BPX Exxon :?~iSt~-0f"AlaSka ',- Mobil ~,~,; ...... ..,., .~:,.,,::. ,, ,, ,~:,,~. ~,. ' Please acknowledge receipt by signing and returning a copy of transmittal. By: ./x~/'~O/~/~ ~.g,~J Date: RECEIVED ARCO Alaslu~ Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-7-93 REFERENCE: ARCO CASED HOLE FINALS ~'Y~i3_- 10-12-92 perf Record Run 1, 5" HIS 7~o;~J3-25~ 8-15-92 PerfRecord Run 1, 5" HLS 8-15-92 Perf Record R,m 1, 5" HLS 9-19-92 Perf Record Run 1, 5" HLS 5-2-92 GR/Temp Log Run 1, 5" HLS ~ 10-17-92 Perf Record Run 1, 5" HLS ~~7S~- 8-21-92 Perf Record Run 1, 5" HLS IL~_~ST 8-22-92 Perf Record Run 1, 5" HLS ~.,.~~.~T 6-23-92 GR/Perf Record Run 1, 5" HLS ~~ 10-19-92 PerfRecord~' '~--- ~ Run1,5" HLS 8-11-92 Perf Record R~m 1, 5" HLS 10-16-92 Perf Record Run 1, 5" HLS Please sign and retu~.~attac~dxFopy as receipt of data. RECEIVEDDaB~.~.~-~~ Sonya Wallace .~ ~ APPROVED ATO-1529 t:~ 0 "1 ~ Trans# 93005 # CHEVRON D &,M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILI2PS PB WEI2, FILES R&D # BPX # STATE OF ALASKA ~CO * The correct API# for 3-34A is 50-029-21132-01. ** The correct API# for 7-4A is 50-029-20292-01. ARCO ~ln_~lr~, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 11-3-92 REFERENCE: ARCO CASED HOLE FINALS 10-3-92 Prod Profile 9-28-92 Leak Detect (Flexstak) 9-14-92 lnj Profile 9-29-92 lnJ Profile 10-2-92 Prod-lnJ (Flexstak) 9-19-92 Leak Detect 9-26-92 GR/Collar 9-27-92 GR/Collar 9-25-92 Prod Profile 9-14-92 Prod Profile lo-2-92 InJ Profile 0-4-02 Prod Profile 10-4-92 lnJ Profile 0-26-02 Prod Prome 9-26-02 GR/Collar 10-5-92 InJ Profile/PITS 9-27-92 InJ Profile 9-19-92 Leak Detect 9-27-92 Prod Profile 10-4-92 InJ/ahut-In Tamp 10-2-92 InJ Profile 10-2-92 InJ Profile (Flexstak) 10-1-92 InJ Profile '0-15-02 InJ Pr(~file 0-17-02 Prod Profile (Flexstak) 10-1-02 Prod Profile 0-28-02 GR/Collar 0-28-02 Prod Profile 9-15-92 Prod Profile 10-1-92 Prod Profile Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1. R~ 1, R~ 1, R~ 1, R~ 1, R~ 1, R~ 1, R~ 1, R~ 1, R~ 1, R~ 1, R~ 1, R~ 1, R~ 1, R~ 1, R~ 1, R~ 1, R~ 1, R~ 1, R~ 1, R~ 1, R~ 1, Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Please sign and returnee attac~e/d copy as receipt of ~C RECEIVED Have A Nice D~ ' / ~' l~laska Oil & Gas 00ns. Sonya W~ce APPROVED =~ ATO- 1529 ~s~ ~224~-~ # CENTRAL FILES # CHEVRON # LUCILLE JOHNSTON # EXXON # MOBIL # PHII,IJPS PB WELL FILES # BPX # STATE OF ALASKA ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 10-9-92 REFERENCE: ARCO DIRECTIONAL DATA ll-7ST ,~ 8-4-2 15-30 ~ ~ 9-2-02 15.31 ~-~ ~-27-~3 16-31 ~7~ 8-11-93 17-16 ~2'"~/ 9-30-02 Magnetic Multi-Shot Survey Job#AK-EI-20056 MWD Directional Survey JobJNA Mvd Directional Survey JobJ,(~wM020821 MWD Directional Survey Job#AK-MW-20075 MWD Directional Survey Job#1117 MWD Directional Survey Job#NA Finder Survey Job#45FGO002027 Please sign and return the attached copy as receipt of data. RECEIVED BY~~___ Have A Nice Day~ Sonya Wallace ATO-1529 APPROVED_~.~___~_ ___ Trans# 92230 Sperry 8ch 8perry 8perry Teleco Teleco 8DII CENTRAL FILES CHEVRON D&M # EXTENSION EXPI~RATION # EXXON MARATHON MOBIL R&D # BPX # ST. o1~ ~ (2 cOPIES) RECEIVED NOV ,1 7 1992. Alaska Oil & G'as cons. commission Anchorage ORIGINAL WELL I-L?.~ LDCATI~: ~T(N/-$) O.OO AZII'IUT4 Flk'~ ROTARY TABLE TO ?~I;ET I$ TIl~ IN POINT(TIP) ~,E~UREI) DHPTH .~U£ VFRT D~'TH I~I~TION AZI,~Lrt'H LATI~JDE(N/-$) DEF'~llJRE(F./-W) 8270,00 7~45,00 20,70 330.00 1E, I2,00 D~.P(E/-W) RECEI,VED / / NOV 1 7 1992 Alaska 011 & Gas Cons. Commission Anchorage F'AC£ ~. 2 I~EY~SUP-dD INT~F.~,'AL UF.~T!CAL DBM'H DEPTH ft ft ft 8270.00 C.O 7845,0C 8667,8~ 3~7,? 8223,90 ~98.66 3~.8 ~)2~3,Z? 8729,96 31,3 8283.10 8760,73 3C.i) ~12,42 8791,79 31,1 8341,99 6823.52 31,7 B372,!~. 8854,23 30,7 8401.32 8~)3,72 5,~ 8429,~ 8913,06 ~,3 8457.C4 F'l~3J~ ~lJ ,~Y 8978,00 64,9 6518.51 SU'ktA~Y CALCULAT!~NS 1'?33. ~6 17,90 3~. 13 1760,80 1936.96 I8,18 ~,19 1944,15 18,38 3~,b'7 1776,73 1949,16 18,77 ~,78 1764,~ 1~4.26 18.84 34,82 1792,06 1965.73 18.~ ~.~ 18(Y9.26 .. i II-07-ST D~PARTLIF~ DIS~b~C~? at ~/-W f~ ft -811,00 1804,51 -821.28 1912.99 -817.21 1910.76 -812.85 1924.54 -60~),43 1~30.17 333.29 3~.02 -~3.4~ 1935.44 35.47 -797.87 1940,50 335.72 -792.29 1945,36 3S5.~7 -786,80 1950,12 33~-2~ -781.32 1954.~8 3~6,44 -769.36 1966.05 DLS dec/ lOOft 4.41 2,52 0,20 1,69 5,05 1,36 0.76 1,40 1.30 0,07 ,A OIL AND GAS CONSERVATION COMMIS ..4 REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate Pull tubing Alter casing Repair well Other X SIDETRACKED 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 253'SNL, 81' WEL, SEC. 33, T11N, R15E, UM At top of productive interval 1530'NSL, 870'WEL, SEC. 28, T11N, R15E, UM At effective depth 1670' NSL, 771' WEL, SEC. 28, TIN, R15E, UM At total depth 1679' NSL, 764' WEL, SECo28, T11N, RISE, UM 12. Present well condition summary Total depth: measured true vertical 5. Type of Well: Development Exploralory Stratigraphic Se~ce X RECEIVED OCT 2 8 1992 Alaska 0il & Gas Cons. ~0mmisst0n Anchorage 6. Datum elevation (DF or KB) KBE -- 62' feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number DS 11-7iST 9... Permit number/approval number Order258 10. APl number 50- 029-20687 11. Field/Pool Prudhoe Bay Field~Oil Pool 9472 feet BKB 8988 feet Plugs (measured) Effective depth: measured true vertical 9430 feet BKB 8948 feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 20" 2659' 13-3/8" Cemented Measured depth True vertical depth 275 sx Permafrost fl 80' 2700 sx Fondu & 2659' 400 sx Permafrost "C" 1380' 7" 302 cu ft Class "G" measured 9296'-9312' 8092'-g472' 80" 2659' 7679'-8988' true vertical 8820'-8835' Tubing (size, grade, and measured depth) 4-1/2", 12~6#, L-80 TDS tubing to 8811'MD Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary 14. 7" TIW "HBBP" permanent packer @ 8750'MD, 4-1/2" Camco TRDP SSSV @ 2192'MD Intervals treated (measured) Treatment description including volumes used and final pressure Representative Daily Averaae Production or Iniection Data -- OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations x Tubing Pressure 16. Status of well classification as: Oil Gas Suspended Service Water Injector. 17. I hereby certify ~hat t~e for~l~loing is trUe and correct to the best of my knowledge. Signed/~//. ~/- Title Drillin~ En~lineer Supervisor Form 10-404 Rev 0~/1~ ~ Date/0 -- SUBMIT IN DUPLICATE BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: DS 11-7 ST BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50-029-20687 PERMIT: APPROVAL: ACCEPT: 07/29/92 07:07 SPUD: RELEASE: 08/08/92 05:08 OPERATION: DRLG RIG: NABORS 2ES WO/C RIG: NABORS 2ES 07/30/92 (1) TD: 0 PB: 0 MIRU MW: 0.0 RELEASED FROM DS 6-12A 19:00 FOR TURNKEY MOVE TO DS 11-7. MOVE RIG, CAMP. 07/31/92 ( 2) TD: 0 PB: 8760 RUNNING VERTILOG IN 9-5/8 CASG MW: 0.0 KILL WELL. NU BOPS & TEST BOPS. PULLED TUBING AND SEAL ASSEMBLY. RUN VERTILOG. 08/01/92 (3) TD: 0 PB: 8760 08/02/92 (4) TD: 0 PB: 8760 08/03/92 (5) TD: 0 PB: 8300 08/04/92 (6) TD: 8860'(8860) CUTTING 9-5/8 SECTION MW: 9.8 WBM CONTINUE RUNNING VERTILOG ON 9-5/8 CASING. TEST BOP. PU BHA #1. RIH 4-1/2 DP. RIH. CHAGE TO MILLING MUD AND SPOT PILL. START CUTTING SECTION AT 8270'. LAY CEMENT PLUG ACROSS WINDOW MW: 9.8 CONTINUE TO CUT 9-5/8 SECTION FROM 8287 - 8334'. 60' WINDOW. PUMP DRY JOB. POOH. RIH W/4-1/2 DP. WASH TO 8434'. REVERSE CIRCULATE. RIH & PIMP CEMENT. WBM KICK OFF PLUG W/DYNA-DRILL MW: 9.7 WBM CONTINUE TO CEMENT KICK OFF PLUG. PUMPED SLURRY AND CLASS G CEMENT W/ ADDITIVES, 0.05 GPS D47 + 1.0% D65 + 0.05% D800, + 0.2 D156. DOWNSQUEEZED 4-1/2 DP. TOC 8174'. POOH W/4-1/2 DP. TEST BOP. PH BHA #2. RIH TO 800'. TEST MWD. RIH W/BHA #2. TAG CEMENT. DYNA-DRILL SLIDE FROM 8277 - 8300'. DRILLING AHEAD W/DYNA-DRILL MW: 9.6 VIS: 48 CONTINUE DYN-DRILL FOR DIRECTION AND AGNLE TO 8860'. 08/05/92 (7) TD: 9318'( 458) 08/06/92 (8) TD: 9472' ( 154) DRILLING AHEAD AT 9318 MW: 9.6 VIS: 49 DRILL TO 8978'. CIRC. RECIPROCATE PIPE. SURVEY. CIRC. POOH W/BHA#2. RIH W/BHA#3. REAM TO 8978'. DRILL TO 9318'. PICK UP 7" LINER MW: 9.6 VIS: 49 DRILL TO 9472'. CIRC. SHORT TRIP. CBU. RIH. DROP SINGLE SHOT SURVEY. RIH W/DLL/AC/CNL/GR RIG UP TO RUN 7" LINER. RE EIV£D OCT 2 8 1992 Alaska 0il & Gas Cons. tfommission Anchorage WELL : DS 11-7 OPERATION: RIG : NABORS 2ES PAGE: 2 08/07/92 (9) TD: 9472 PB: 9430 08/08/92 (10) TD: 9472 PB: 9430 CHANGE WELL OVER TO SEAWATER MW: 9.7 WBM RIH W/7" LINER ASSY. CIRCULATE. RIH W/4-1/2 DP. CIRCULATE. RIH W/7" LINER. WASH FROM 9444 TO 9472' RECIPROCATE PIPE. CIRCULATE. PUMP SEAWATER. TEST LINES. PUMP SPACER AND CEMENT CLASS G CEMENT WITH 0.05 GAL/SK D47 + 0.4% D65 + 0.1 GAL/SK D135 + 1.0 GAL/SK D600 + 0.15 DS00 @ 5 BPM /400 PSI. SET LINER HANGER. SET LINER PACKER.. RELEASE FROM PACKER. REVERSE CIRCULATE. PUMP DRY JOB. RIH W/BHA#3. RIH W/BHA#4. REVERSE CIRCULATE. PRESSURE TEST PACKER & 9-5/8 I MW: 8.6 Seawater REVERSE CIRCULATE. TEST LINER LAP. RIH W/4-1/2 TUBING. LAND TUBING. REVERSE CIRCULATE. 08/09/92 (11) TD: 9472 PB: 9430 MOVE RIG TO DS 18-9A MW: 8.6 Seawater NU TREE. PULL TREE TEST PLUG. TEST HANGER SEALS. PRESSURE TEST TUBING. SET BPV. SECURE TREE. RELEASE RIG 1730 HRS. 8/8/92. SIGNATURE: (drilling superintendent) DATE: R'ECEIVED & Bas Cons. e;ornmissior~ Anchorage PRUDHOE BAY DRILLIN~ DS 11-07 ST R'E6E[VED OOT ~ 8 199~ Alaska Oil & Gas Cons. Anchorage GREAT LAND DIRECTIONAL DRILLING, INC. REPORT OF SUB-SURFACE DIRECTIONAL SURVEY PRUDHOE BAY DRILING COMPANY DS 11-07 ST WELL NAME PRUDHOE BAY LOCATION AL892D35 JOB NUMBER ROBERT WALL MWD TYPE SURVEY DIRECTIONAL SUPERVISOR NAME TITLE 08/13/92 DATE SIGNATURE TIE IN @ 8270.0 FT DEPTH INTERVAL FROM 9472.0 FT TO 08/01/92 08/06/92 DATE SURVEY TAKEN FROM TO THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL WE HAVE RETAINED A COPY OF YOUR SURVEY REPORT IN OUR FILES FOR YOUR CONVENIENCE; HOWEVER, SHOULD YOU SO DESIRE, ALL COPIES OF THE SURVEY REPORT WILL BE FORWARDED TO YOU ON WRITTEN REQUEST. ALL SURVEYS ARE KEPT IN A LOCKED FILE AND ARE HELD IN STRICTEST CONFIDENCE. GREAT LAND DIRECTIONAL DRILLING, Client · Field ..... : Well ...... : Section at: Engineer..: PRUDHOE BAY DRILLING PRUDHOE BAY DS 11-07 ST N,26.49,E ROBERT WALL INC. S MEAS INCLN C DEPTH ANGLE 7 0 0.00 7 100 0.00 7 200 0.25 7 300 0.25 7 400 0.00 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 0.0 -62.0 0.0 100.0 38.0 0.0 200.0 138.0 -0.2 300.0 238.0 -0.7 400.0 338.0 -0.9 7 500 0.25 500.0 438.0 7 600 0.25 600.0 538.0 7 700 0.50 700.0 638.0 7 800 0.00 800.0 738.0 7 900 0.25 900.0 838.0 7 1000 0.25 1000.0 938.0 7 1100 0.50 1100.0 1038.0 7 1200 0.00 1200.0 1138.0 7 1300 0.25 1300.0 1238.0 7 1400 0.50 1400.0 1338.0 7 1500 0.25 1500.0 1438.0 7 1600 0.50 1600.0 1538.0 7 1700 0.50 1700.0 1638.0 7 1800 0.50 1800.0 1738.0 7 1900 0.50 1900.0 1838.0 7 2000 0.25 2000.0 1938.0 ^Survey Codes: 7/GYRO (GLDD (c)92 DSll07ST B1.30 4:52 PM 2) RECORD OF SURVEY DIRECTION BEARING S 0.00 E S 0.00 E S 31.00 W S 33.00 W S 0.00 E -1.1 S 25.00 W -1.5 S 23.00 E -1.9 S 26.00 E -2.1 S 0.00 E -2.4 S 28.00 W -2.8 S 13.00 W -3.3 S 34.00 E -3.5 S 0.00 E -3.6 S 81.00 W -4.1 S 58.00 W Computation...: Survey Date...: KB Elevation..: Reference ..... : Magnetic Dcln.: 08/13/92 RADIUS OF CURVATURE 08/06/92 62.00 ft AL892D35 30.26 E -4.6 -5.0 -5.4 -5.9 -6.6 -7.2 RELATIVE-COORDINATES FROM-WELL-HEAD 0.0N 0.0E 0.0N 0.0E 0.2S 0.1W 0.6S 0.3W 0.7S 0.5W 0.9 S 0.6 W 1.4 S 0.6 W 2.0 S 0.3 W 2.3 S 0.1 W 2.5 S 0.2 W 2.9 S 0.4 W 3.6 S 0.2 W 3.9 S 0.0 E 4.0 S 0.2 W 4.2 S 0.8 W S 80.00 W 4.4 S 1.4 W S 80.00 W 4.5 S 2.1 W N 86.00 W 4.6 S 2.9 W S 79.00 W 4.6 S 3.8 W S 42.00 W 5.1 S 4.6 W S 27.00 W 5.6 S 4.9 W CLOSURE DL DISTNCE BEARING / 100 0.0 N 0.00 E 0.00 0.0 N 0.00 E 0.00 0.2 S 31.00 W 0.25 0.7 S 31.67 W 0.00 0.9 S 32.00 W 0.25 1.1 S 30.60 W 0.25 1.5 S 22.43 W 0.00 2.0 S 8.45 W 0.25 2.4 S 2.42 W 0.50 2.5 S 4.54 W 0.25 3.0 S 6.85 W 0.00~. 3.6 S 3.81 W 0.25 3.9 S 0.08 E 0.50 4.0 S 3.02 W 0.25 4.3 S 11.03 W 0.25 4.7 S 17.84 W 0.25 5.0 S 24.49 W 0.25 5.5 S 32.63 W 0.00 6.0 S 39.35 W 0.00 6.8 S 41.96 W 0.00 7.5 S 41.31 W 0.25 DS 11-07 ST S MEAS INCLN C DEPTH ANGLE 7 2100 0.25 7 2200 1.75 7 2300 1.75 7 2400 2.00 7 2500 2.00 7 2600 1.75 7 2700 1.75 7 2800 1.75 7 2900 1.75 7 3000 1.75 7 3100 0.50 7 3200 0.50 7 3300 0.25 7 3400 0.25 7 3500 0.00 7 3600 0.25 7 3700 2.50 7 3800 5.75 7 3900 9.50 7 4000 12.25 7 4100 14.25 7 4200 14.50 7 4300 14.75 7 4400 15.00 7 4500 15.50 7 4600 15.75 7 4700 16.00 7 4800 16.00 7 4900 16.25 7 5000 17.50 VERTICAL-DEPTHS BKB SUB-SEA 2100.0 2038.0 2199.9 2137.9 2299.9 2237.9 2399.8 2337.8 2499.8 2437.8 2599.7 2537.7 2699.7 2637.7 2799.6 2737.6 2899.6 2837.6 2999.5 2937.5 3099.5 3037.5 3199.5 3137.5 3299.5 3237.5 3399.5 3337.5 3499.5 3437.5 3599.5 3537.5 3699.5 3637.5 3799.2 3737.2 3898.3 3836.3 3996.5 3934.5 4093.8 4031.8 4190.7 4128.7 4287.5 4225.5 4384.1 4322.1 4480.6 4418.6 SECTION DISTNCE RECORD OF SURVEY -7.4 -6.1 -3.4 -0.6 2.1 3.8 4.5 4.7 4.4 3.4 DIRECTION BEARING N 80.00 E N 55.00 E N 59.00 E N 57.00 E N 71.00 E RELATIVE-COORDINATES FROM-WELL-HEAD 5.9 S 4.7 W 5.2 S 3.1 W 3.6 S 0.6 W 1.8 S 2.2 E 0.3 S 5.3 E S 82.00 E 0.0 N 8.6 E S 70.00 E 0.7 S 11.5 E S 64.00 E 1.9 S 14.3 E S 54.00 E 3.5 S 17.0 E S 32.00 E 5.7 S 19.0 E 2.4 S 34.00 E 1.7 S 20.00 W 1.0 S 26.00 W 0.6 S 20.00 E 0.5 S 0.00 E 0.3 -1.3 0.0 4.6 13.1 7.4 S 20.1 E 8.2 S 20.2 E 8.8 S 19.9 E 9.2 S 19.9 E 9.4 S 20.0 E S 10.00 W 9.6 S 20.0 E N 58.00 W 10.5 S 18.1 E N 48.00 W 6.1 S 12.4 E N 39.00 W 3.5 N 3.2 E N 34.00 W 18.6 N 8.0 W N 39.00 W 37.0 N 21.6 W N 39.00 W 56.3 N 37.2 W N 37.00 W 76.2 N 52.8 W N 37.00 W 96.7 N 68.2 W N 37.00 W 117.7 N 84.1 W 23.5 33.8 44.7 56.2 67.9 4576.9 4514.9 79.9 4673.1 4611.1 92.3 4769.2 4707.2 105.3 4865.3 4803.3 118.7 4961.0 4899.0 133.3 N 37.00 W 139.3 N 100.3 W N 36.00 W 161.2 N 116.5 W N 35.00 W 183.7 N 132.5 W N 34.00 W 206.6 N 148.3 W N 33.00 W 230.8 N 164.3 W Page 2 08/13/92 CLOSURE DISTNCE BEARING 7.5 S 38.69 W 6.1 S 30.81 W 3.6 S 8.85 W 2.9 S 50.53 E 5.4 S 86.77 E DL /1oo 0.00 1.50 0.00 0.25 0.02 8.6 N 89.94 E 0.25 11.6 S 86.39 E 0.01 14.5 S 82.37 E 0.01 17.3 S 78.36 E 0.01 19.9 S 73.29 E 0.02 21.4 S 69.89 E 1.25 21.8 S 67.92 E 0.00 21.8 S 66.20 E 0.25 22.0 S 65.17 E 0.00 22.1 S 64.77 E 0.25 22.2 S 64.22 E 0.25 20.9 S 59.96 E 2.26~-~ 13.8 S 63.57 E 3.25 4.7 N 43.04 E 3.76 20.3 N 23.18 W 2.76 42.9 N 30.25 W 2.02 67.5 N 33.46 W 0.25 92.7 N 34.69 W 0.28 118.4 N 35.19 W 0.25 144.7 N 35.52 W 0.50 171.6 N 35.75 W 0.25 198.9 N 35.86 W 0.26 226.5 N 35.81 W 0.08 254.3 N 35.67 W 0.26 283.3 N 35.45 W 1.25 ^Survey Codes: 7/GYRO DS 11-07 ST MEAS DEPTH 5100 5200 5300 5400 5500 INCLN ANGLE VERTICAL-DEPTHS BKB SUB-SEA 20.25 5055.6 4993.6 24.00 5148.2 5086.2 26.75 5238.5 5176.5 29.00 5326.9 5264.9 29.75 5414.1 5352.1 7 5600 29.75 7 5700 30.00 7 5800 30.25 7 5900 31.00 7 6000 31.00 7 6100 31.00 7 6200 31.75 7 6300 31.75 7 6400 32.00 7 6500 32.00 7 6600 32.00 7 6700 31.75 7 6800 31.75 7 6900 31.00 7 7000 31.00 7 7100 29.00 7 7200 27.50 7 7300 27.00 7 7400 26.25 7 7500 26.00 7 7600 25.75 7 7700 25.00 7 7800 24.25 7 7900 24.00 7 8000 23.00 5500.9 5438.9 5587.6 5525.6 5674.1 5612.1 5760.2 5698.2 5845.9 5783.9 5931.6 5869.6 6017.0 5955.0 6102.0 6040.0 6186.9 6124.9 6271.7 6209.7 6356.5 6294.5 6441.4 6379.4 6526.5 6464.5 6611.9 6549.9 6697.6 6635.6 6784.2 6722.2 6872.3 6810.3 6961.2 6899.2 7050.6 6988.6 7140.3 7078.3 7230.3 7168.3 7320.7 7258.7 7411.6 7349.6 7502.8 7440.8 7594.5 7532.5 RECORD OF SURVEY SECTION DISTNCE DIRECTION BEARING RELATIVE-COORDINATES FROM-WELL-HEAD 150.2 N 31.00 W 258.2 N 181.4 W 171.2 N 28.00 W 291.0 N 200.0 W 196.4 N 27.00 W 329.0 N 219.8 W 224.2 N 27.00 W 370.6 N 241.0 W 253.8 N 26.00 W 414.5 N 262.9 W N 25.00 W 459.3 N 284.2 W N 24.00 W 504.7 N 304.9 W N 23.00 W 550.7 N 324.9 W N 22.00 W 597.7 N 344.4 W N 21.00 W 645.7 N 363.3 W 284.3 315.7 347.9 381.4 415.8 450.6 N 21.00 W 693.7 N 381.7 W 486.5 N 19.00 W 742.7 N 399.5 W 522.7 N 21.00 W 792.1 N 417.5 W 558.7 N 20.00 W 841.6 N 436.0 W 595.2 N 20.00 W 891.4 N 454.1 W 631.7 N 20.00 W 941.2 N 472.3 W 668.1 N 20.00 W 990.8 N 490.3 W 704.0 N 21.00 W 1040.1 N 508.8 W 739.1 N 21.00 W 1088.7 N 527.4 W 773.9 N 21.00 W 1136.8 N 545.9 W 805.7 N 27.00 W 1182.4 N 566.2 W 832.5 N 31.00 W 1223.8 N 589.1 W 857.1 N 31.00 W 1263.1 N 612.7 W 881.9 N 29.00 W 1301.9 N 635.1 W 906.5 N 30.00 W 1340.2 N 656.8 W 930.6 N 30.00 W 1378.0 N 678.6 W 954.3 N 30.00 W 1415.1 N 700.1 W 977.3 N 30.00 W 1451.2 N 720.9 W 999.5 N 31.00 W 1486.4 N 741.6 W 1021.6 N 29.00 W 1520.9 N 761.6 W Page 3 08/13/92 CLOSURE DISTNCE BEARING 315.6 N 35.09 W 353.1 N 34.50 W 395.6 N 33.74 W 442.1 N 33.03 W 490.9 N 32.38 W 540.2 N 31.75 W 589.6 N 31.14 W 639.4 N 30.54 W 689.9 N 29.95 W 740.8 N 29.36 W 791.8 N 28.82 W 843.3 N 28.28 W 895.4 N 27.79 W 947.8 N 27.39 W 1000.4 N 27.00 W 1053.0 N 26.65 W 1105.5 N 26.33 W 1157.8 N 26.07 W 1209.7 N 25.85 W 1261.0 N 25.65 W 1311.0 N 25.59 W 1358.2 N 25.71 W 1403.8 N 25.88 W 1448.5 N 26.01 W 1492.5 N 26.11 W 1536.0 N 26.22 W 1578.8 N 26.32 W 1620.4 N 26.42 W 1661.1 N 26.52 W 1700.9 N 26.60 W DL /lOO 2.76 3 . 78 '~' 2.76 2.25 0.79 0.25 0.35 0.36 0.80 0.27 0.00 0.93 0.55 0.38 0.00 0.00 0.25 '""~., 0.28 0.75 0.00 2.45 1.73 0.50 0.85 0.32 0.25 0.75 0.75 0.30 1.05 ^Survey Codes: 7/GYRO DS 11-07 ST S MEAS INCLN C DEPTH ANGLE 7 8100 22.25 7 8200 21.75 3 8270 20.70 3 8668 17.40 3 8761 17.80 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 7686.8 7624.8 1043.3 7779.6 7717.6 1064.3 7844.8 7782.8 1078.3 8221.0 8159.0 1187.5 8309.6 8247.6 1215.6 3 8851 18.40 8395.2 8333.2 3 8913 18.80 8453.9 8391.9 1 9412 15.50 8930.7 8868.7 J 9472 15.30 8988.5 8926.5 RECORD OF SURVEY ^Survey Codes: I/SINGLE SHOT 3/MWD DIRECTION RELATIVE-COORDINATES BEARING FROM-WELL-HEAD N 29.00 W 1554.6 N 780.2 W N 30.00 W 1587.2 N 798.7 W N 30.00 W 1609.1 N 811.3 W N 24.80 E 1734.0 N 817.0 W N 29.00 E 1759.1 N 804.3 W 1243.4 N 35.60 E 1782.7 N 789.4 W 1263.0 N 34.80 E 1798.8 N 778.0 W 1408.3 N 36.00 E 1918.8 N 692.7 W 1424.0 N 36.20 E 1931.6 N 683.4 W 7/GYRO J/PROJECTED Page 4 08/13/92 CLOSURE DISTNCE BEARING 1739.4 N 26.65 W 1776.8 N 26.71 W 1802.1 N 26.76 W 1916.8 N 25.23 W 1934.2 N 24.57 W 1949.6 N 23.88 W 1959.9 N 23.39 W 2040.0 N 19.85 W 2048.9 N 19.48 W DL /1oo 0.75 0.52 1.50 1.48 0.60 0.99 0.66 0.66 0.33 DS 11-07 ST Page 5 08/13/92 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL SUBSEA MEAS INCLN TVD DEPTH DEPTH ANGLE BKB MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 100 162 0.16 162 0 0 S 31.00 W 0.07 S 0.04 W 200 262 0.25 262 0 0 S 32.24 W 0.42 S 0.25 W 300 362 0.09 362 0 0 S 12.54 W 0.71 S 0.45 W 400 462 0.16 462 0 0 S 25.00 W 0.82 S 0.50 W 500 562 0.25 562 0 0 S 4.76 E 1.20 S 0.60 W 600 662 0.41 662 0 0 S 24.86 E 1.69 S 0.42 W 700 762 0.19 762 0 0 S 9.88 E 2.31 S 0.18 W 800 862 0.16 862 0 0 S 28.00 W 2.42 S 0.14 W 900 962 0.25 962 0 0 S 18.70 W 2.79 S 0.31 W 1000 1062 0.41 1062 0 0 S 16.14 E 3.30 S 0.34 W 1100 1162 0.19 1162 0 0 S 12.92 E 3.92 S 0.09 W 1200 1262 0.16 1262 0 0 S 81.00 W 3.95 S 0.08 W 1300 1362 0.41 1362 0 0 S 66.74 W 4.07 S 0.55 W 1400 1462 0.34 1462 0 0 S 71.64 W 4.39 S 1.23 W 1500 1562 0.41 1562 0 0 S 80.00 W 4.49 S 1.77 W 1600 1662 0.50 1662 0 0 S 88.68 W 4.60 S 2.61 W 1700 1762 0.50 1762 0 0 S 84.70 W 4.60 S 3.48 W 1800 1862 0.50 1862 0 0 S 56.05 W 4.85 S 4.31 W 1900 1962 0.34 1962 0 0 S 32.70 W 5.43 S 4.83 W 2000 2062 0.25 2062 0 0 S 51.78 E 5.85 S 4.87 W 2100 2162 1.18 2162 0 0 N 64.49 E 5.65 S 3.98 W 2200 2262 1.75 2262 0 0 N 57.48 E 4.17 S 1.54 W 2300 2362 1.91 2362 0 0 N 57.76 E 2.52 S 1.13 E 2400 2462 2.00 2462 0 0 N 65.71 E 0.79 S 4.12 E 2500 2562 1.84 2562 0 0 N 87.81 E 0.08 N 7.39 E 2600 2662 1.75 2662 0 0 S 74.52 E 0.38 S 10.44 E 2700 2762 1.75 2762 0 0 S 66.26 E 1.44 S 13.30 E 2800 2862 1.75 2862 0 0 S 57.76 E 2.85 S 16.01 E 2900 2962 1.75 2962 0 0 S 40.26 E 4.79 S 18.35 E 3000 3062 0.97 3062 0 0 S 33.25 E 6.96 S 19.83 E DS 11-07 ST Page 6 08/13/92 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL SUBSEA MEAS INCLN TVD DEPTH DEPTH ANGLE BKB MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 3100 3162 0.50 3162 0 0 S 0.26 E 7.87 S 20.26 E 3200 3262 0.34 3262 0 0 S 23.75 W 8.62 S 20.03 E 3300 3362 0.25 3362 0 0 S 2.74 E 9.06 S 19.89 E 3400 3462 0.09 3462 0 0 S 7.50 E 9.40 S 19.99 E 3500 3562 0.16 3562 0 0 S 10.00 W 9.51 S 19.98 E 3600 3662 1.66 3662 0 0 S 79.99 W 10.33 S 19.27 E 3700 3763 4.54 3762 1 0 N 51.74 W 8.26 S 14.96 E 3800 3863 8.12 3862 1 1 N 42.31 W 0.76 S 6.95 E 3900 3965 11.28 3962 3 1 N 35.76 W 12.75 N 3.85 W 4000 4067 13.59 4062 5 2 N 37.36 W 30.83 N 16.74 W 4100 4170 14.43 4162 8 3 N 39.00 W 50.59 N 32.57 W 4200 4274 14.68 4262 12 3 N 37.53 W 70.91 N 48.72 W 4300 4377 14.94 4362 15 3 N 37.00 W 92.02 N 64.66 W 4400 4481 15.40 4462 19 4 N 37.00 W 113.64 N 80.96 W 4500 4585 15.71 4562 23 4 N 37.00 W 135.90 N 97.74 W 4600 4688 15.97 4662 26 4 N 36.12 W 158.68 N 114.66 W 4700 4792 16.00 4762 30 4 N 35.08 W 181.99 N 131.35 W 4800 4897 16.24 4862 35 4 N 34.03 W 205.78 N 147.74 W 4900 5001 17.53 4962 39 4 N 32.98 W 231.05 N 164.47 W 5000 5107 20.51 5062 45 6 N 30.79 W 260.25 N 182.66 W 5100 5215 24.42 5162 53 8 N 27.85 W 296.46 N 202.88 W 5200 5326 27.34 5262 64 11 N 27.00 W 339.66 N 225.19 W 5300 5440 29.30 5362 78 14 N 26.60 W 388.10 N 249.80 W 5400 5555 29.75 5462 93 15 N 25.45 W 439.22 N 274.76 W 5500 5670 29.93 5562 108 15 N 24.30 W 491.18 N 298.85 W 5600 5786 30.21 5662 124 16 N 23.14 W 544.19 N 322.14 W 5700 5902 31.00 5762 140 16 N 21.98 W 598.77 N 344.81 W 5800 6019 31.00 5862 157 17 N 21.00 W 654.71 N 366.74 W 5900 6136 31.27 5962 174 17 N 20.29 W 710.93 N 388.20 W 6000 6253 31.75 6062 191 17 N 20.06 W 768.93 N 408.85 W DS 11-07 ST DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL Page 7 08/13/92 SUBSEA MEAS INCLN TVD DEPTH DEPTH ANGLE BKB 6100 6200 6300 6400 6500 MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 6600 6700 6800 6900 7000 6371 31.93 6162 209 18 N 20.29 W 826.97 N 6489 32.00 6262 227 18 N 20.00 W 885.66 N 6606 31.98 6362 244 18 N 20.00 W 944.38 N 6724 31.75 6462 262 18 N 20.24 W 1002.73 N 6842 31.44 6562 280 18 N 21.00 W 1060.47 N 7100 7200 7300 7400 7500 6958 31.00 6662 296 17 N 21.00 W 1116.81 N 7075 29.51 6762 313 16 N 25.47 W 1171.28 N 7188 27.67 6862 326 14 N 30.54 W 1219.20 N 7301 26.99 6962 339 13 N 30.98 W 1263.42 N 7413 26.22 7062 351 12 N 29.13 W 1306.79 N 7600 7700 7800 7900 8000 7524 25.94 7162 362 11 N 30.00 W 1349.32 N 7635 25.49 7262 373 11 N 30.00 W 1391.14 N 7746 24.66 7362 384 10 N 30.00 W 1431.65 N 7855 24.11 7462 393 10 N 30.55 W 1470.73 N 7965 23.35 7562 403 9 N 29.71 W 1508.78 N 8100 8200 8300 8400 8500 8073 22.45 7662 411 9 N 29.00 W 1545.63 N 8181 21.84 7762 419 8 N 29.81 W 1581.08 N 8288 20.55 7862 426 7 N 27.47 W 1614.79 N 8395 19.66 7962 433 6 N 12.81 W 1649.07 N 8501 18.79 8062 439 6 N 1.77 E 1683.75 N 8600 8700 8800 8900 8606 17.91 8162 444 5 N 16.28 E 1716.47 N 8711 17.59 8262 449 5 N 26.74 E 1745.63 N 8816 18.17 8362 454 5 N 33.04 E 1773.63 N 8922 18.74 8462 460 5 N 34.82 E 1801.09 N 9027 18.05 8562 465 5 N 35.07 E 1828.35 N 9132 17.35 8662 470 5 N 35.33 E 1854.43 N 9236 16.66 8762 474 5 N 35.58 E 1879.34 N 9341 15.97 8862 479 4 N 35.83 E 1903.10 N 9445 15.39 8962 483 4 N 36.11 E 1925.76 N 430.67 W 452.07 W 473.44 W 494.71 W 516.59 W 538.22 W 560.70 W 586.40 W 612.95 W 637.87 W 662.09 W 686.23 W 709.62 W 732.31 W 754.75 W 775.27 W 795.17 W 814.45 W 827.01 W 830.11 W 824.26 W 811.39 W 795.53 W 776.40 W 757.35 W 738.95 W 721.20 W 704.10 W 687.64 W DS 11-07 ST Page 8 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL 08/13/92 MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES CLOSURE DL/ DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD DIST BEARING 100 0 0.00 0 -62 1000 0.25 1000 938 2000 0.25 2000 1938 3000 1.75 3000 2938 4000 12.25 3997 3935 0 N 0.00 E 0 N 0 E -3 S 13.00 W 3 S 0 W -7 S 27.00 W 6 S 5 W 3 S 32.00 E 6 S 19 E 13 N 34.00 W 19 N 8 W 0 N 90.00 E 0.0 3 S 6.85 W 0.0 7 S 41.31 W 0.3 20 S 73.29 E 0.0 20 N 23.18 W 2.8 5000 17.50 4961 4899 133 N 33.00 W 231 N 6000 31.00 5846 5784 416 N 21.00 W 646 N 7000 31.00 6698 6636 774 N 21.00 W 1137 N 8000 23.00 7595 7533 1022 N 29.00 W 1521 N 9000 18.22 8536 8474 1290 N 35.01 E 1821 N 164 W 283 N 35.45 W 1.3 363 W 741 N 29.36 W 0.3 546 W 1261 N 25.65 W 0.0 762 W 1701 N 26.60 W 1.0 762 W 1975 N 22.71 W 0.7 PRUDHOE BAY Harker Identi f tca~ ion HI) N/S A) KB 0 ON B) TIE-IN / KOP 8270 i609 N C) 'rD 9472 ~.932 N E/Il 663 ii DS ~-07 ST PLAN VIEW CLOSURE ..... : 2049 fi at N ~9.4B N DECLINATION.: 30.26 E SCALE ....... : ! inch = 300 leek DRAWN ....... : OB/t4/92 ;IDETRACK #ELL i950 i600 i650 '1500 i350 i200 i050 900 750 6OO 450 3OO t50 0 i50 4- NEST · EAST -> PRUBHOE BAY % t t ORIGINAL #ELL tooo ttoo i2oo t~oo t4oo t5oo Sect ~on Departure i600 ~700 DRILLING DS ~-07 ST VERT T CAL SECTT ON V T EH Section at: N 28.49 E TVD Scale.: I inch = 200 feet Dep Scale.: t inch = 200 fee~ Drawn ..... : 08/t4/92 Sreat Land DJrectJonaJ Dr J J] Jrt9 .... ,_,.~.~.,_~.. ,1 ,,, ~ _ _~, Narker Iden~tf~ca~ion ND BKB SECTN INCLN A} TIE-IN / KOP 8270 7845 t078 20.70 BI TD 9472 8989 t424 ~5.30 ARCO Alask~ Inc. P.O.Box 100360 Anchorage, Alaska 99510 ' DATE: 10-2-92 REFERENCE: ARCO CASED HOLE ~Z-/~f~ 1-20 9-3-92 CNL/GR/~ R,m ~z-~ 2-21 8-30-92 CCL~~ - ~.a~.~ ~___~ 2-34 9-13-92 PIS R~m '--~-*~~ 9-14-92 PDK-100/GR/CCL 8-29-92 CCL/PerI ~ fl-l~t 9-5-92 CCL~ R~m /-~/~ 11-7ST GR/C~/J~ R~ _ _ _ 8-16-92 C~ R~ ~ 16-10 _ 9-6-92 C~~ R~m ~~~-gA ~ ~13-92 ~/~ ~ [1S-gA 9-12-92 ~/~ l e 511 1, ,5" 1, 5" 1, 5" 1, 5" 1, 5" 1, 5" 1, 5" 1, 5" 2" & Please sign and return the~ettached~opy as ~ei~~ of data. Have A Nic. Da~]~ R'EC/EIVED SonyaWallace OCT 0 5 1992 ATO- 1529 · aJaska Oil & Gas Cons. Commission Anchorage # ~l/~ON # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WEI~ FILES R&D # BPX # STATE OF ALASKA TEXACO .7 ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 9-15-92 REFERENCE: ARCO MAGNETIC TAPE(S) WITH LISTINGS Job~102262 Job~AK-MM-911231 Job~AK-MM-920104 Jo~ Please sign and return the attached copy as receipt of data. RECEIVED BY~__~.~ Have A Nice Day~ Sonya Wallace AT0-1529 APPROVED_~_~_ ____ Trans# 92206 Atlas Sperry Sperry Sch CE~rraAL Fmcs (CH) CHEVRON D&M # ~Oa OC~NAS (Oa/aCT) # EXXON MARATHON MOBIL # PHILIXPS PB WELL ~ R&D # BPX # STATE OF ~KA TEXACO RECEIVED S EP 2 5 199~. Alaska Oil 8, Gas Cons. Commisslort Anchorage ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 8-18-92 REFERENCE: ARCO OPEN HOLE FINALS 8-5-92 SSTVD Color Run 8-5-92 DLL/MSFL/GR Color Run 8-5-92 BHCS/GR Color Run 8-5-92 CNL/GR Color Run 8-6-92 SSTVD Run 8-6-92 DLL/GR Run 8-6-92 BHCA/GR Rrm 8-6-92 CNL/GR Run 8-9-92 SSTVD Run 8-9-92 PISFL Run 8-9-92 BHCS Run 1, 1"&2' Sch 1. :~'&5" Sch 1, 2'&.~' Sch 1, 2'&~' Sch 1, 1"&2' Atlas 1, 2'&,~' Atlas 1, 2'&~' Atlas 1, :~'&,~' Atlas 1, 1"~ Sch 1, 2"&5~\Sch 1, 2'&~' ~Sch Please sign and return the attached copy as receipt of data. Have i Nice Day!.~ Sonya Wallace APPROVED ATO- 1529 Trans# 9218~-~r # CENTRAL FILES # CHEVRON #D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS # PB WELL FILES R&D. # BPX # STATE OF ALASKA # TEXACO RECEIVED SEP 03 1992 Naska Oil & Gas Cons. Commission Anchorage ARCO ~-~k~, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 8-14-92 REFERENCE: ARCO CASED HOLE FINALS 7-26-92 CNL/GR/CCL Run 1, 5" 7-26-92 CNL/GR/CCL Run 1, 5" 7-31-92 CNL/GR/CCL Run 1, 5" 8-1-92 CNL/GR/ CL Run 1, 5" 8-1-92 CNL/GR/CCL Run 1, 5" 7-23-92 CCL Run 1, 5" 7-30-92 CNL/GR/CCL Run 1, 5" 7-25-92 C(~ Run 1, 5" 7-31-92 CNL/GR/CCL Run 1, 5" 7-25-92 CCL Run 1, 5" 7-27-92 CCL Run 1, 5" 7-26-92 'Collar (Jet Cutter Rec) Run 1, 5" 7-30-92 CNL/GR/CCL Run 1, 5" 8-2-92 CCL'(Tubing Patch) Run 1, 5" 7-26-92 CCL (Peri) Run 1, 5" 7-31-92 Vertilog Run 1, 5" 7-24-92 CNL/GR/CCL Run 1, 5" 7-28-92 CNL/GR/CCL Run 1, 5" 7-28-92 CNL/GR/CCL Run 1, 5" 7-27-92 CCL (Tubing Cutter Rec) Run 1, 5" Please sign and return~ttac/~/~py~ei~ ~~V ED ~ve A Nice ~ / Alaska 011 & Gas C0n~ C~~ # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO * The correct API# for 2-3 is 50-029-20077. Prudhoe Bay Unit P. O. Box 196612 Anchorage, Alaska 99519-6612 Attention: Nabors 2ES Drilling Engineer: August 6, 1992 I have compiled a summary of Anadrill's performance on DS ll-07-ST, Nabors 2ES. SERVICES PROVIDED Directional MWD with DWOB and DTOR were picked up on August 2, 1992 and used to kick off the sidetrack from 8279'. Valid MWD surveys were obtained from 8668' (survey depth) to 8913' (survey depth). After completing the kickoff the motor and the MWD tool were laid down on August 4, 1992 at a total depth of 8978'. JOB PERFORMANCE As on previous wells DWOB measurements rather than time drilling were used with MWD gravity tool face readings to efficiently kick off the well. The kickoff went extremely well with no problems of any kind encountered. For your convenience, I have included a hardcopy of all of the survey files and also a copy of the surveys accepted by the Directonal Driller. I have also included a copy of the Sticking Pipe INdicator (SPIN) log. Anadrill appreciates the opportunity to supply services on your well and we look forward to continuirig a healthy business relationship. Thank you, Manager-Alaska ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-31-92 REFERENCE: ARCO CASED HOLE FINAI~ 7-12-92 CCL/Perf 7-18-92 CCL/Perf 7-6-92 Prod/Press/Spin/Temp/Trap 7-6-92 CCL/Perf 7-13-92 C~L/Perf 7-12-92 CCL/Perf 7-13-92 CCL/Perf 7-11-92 CCL/Tubing Cutter 5-30-92 MAI Acoustic Filtered Waveforms 5-30-92 BHC MAI Comp Slowness Curves 7-1 1-92 PFC/GR 7-13-92 Collar/Perf 7-12-92 PFC/GR. 7-12-92 CCL/Perf 7-19-92 CCL/Tubing Cutter Run 1, 5" Atlas Run 1, ~' Atlas Run 1, ~' Sch Run 1, ~' Atlas Run 1, ~' Atlas Run 1, ~' Atlas Run 1, ~' Atlas Run 1, ~' Atlas Run 2, ~' Atlas 'Run 2, 2' & {~' Atlas Run 1, {~' Atlas Run 1, ~' Atlas Run 1. ~' Atlas Run 1, ~' Atlas Run 1. [~' Atlas Please sign and return 'the'attached copy as receipt of data. RECEIVED B Y___~~~_~_~____ .... Have A Nice Day! Sonya W_~ll~_ce ATO- 1529 APPROVED Trans# 9217~- # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ,~T.&SKA TEXACO RECEIVE1) AUG 1 0 199 Alaska 0il & Gas Oons. Commission Anchorage ' TO: THRU: FROM: MEMORANDUM of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION David W Johns_to~ Commissioner~ DATE: FILE NO: July 14, 1992 lg714-3.doc Blair Wondzell ~i~ P. I. SupervisorT/'6 FLouis R Grimaldi Petr Inspector TELEPHONE NO: SUBJECT: Well Bore Plug ARCO DS 11-7 Prudhoe Bay Unit $/- ,, Wednesday. July 8. 1992 I witnessed the tag and pressure test for verification of plug integrity in ARCO's DS 11-7 in the Prudhoe Bay Unit. This well is being prepared for a side track making this a bottom hole abandonment only. The tag was made by wireline and appeared solid; the plug then held a 1500 psi pressure test for 30 minutes. In s~arv,. I witnessed the verification of plug placement on ARCO's DS 11-7 in the Pru~oe Bay Unit. .. Attachments 02-001A (Rev. 6/89) 20/11/MEMO1.PM3 Operator Company Repr Lease No. STATE OF ALASKA SKA OIL & GAS CONSERVATION Plug & Abandonment Reporf Well No. Total Depth ~3~OElevation "O.D. Set at "O.D. @ "O.D. @ Casing: Drive Pipe Conductor Intermediate Plugging Data: 1. Open hole plugs: Well ~SION Date 7-- ~'- ~'~ Drilling Permit # Sec. T-R Ft. w/ Pene. Ft. Surface "O.D. @ ~ Open hole isolation plug: 5. Casing stub plugs: 6. Surface plug Casing removal: REMARKS: "casing cut at ' "casing cut at ' "casing cut at ' JUL 2 '92 14:40 FROM PB-'OPS-ENG TO PEGGY PAGE 5~Hdm,~ 77¢ AR3B-6287 -Well 11-7 Spud Date: 01-31-82 ~riginal RKBE: 62' ~op of Sadlerochit: 8&52' Annulus Fluid: Diesel/9.8# NaCI All De ,tbs are ,4 Ar&/ Alaska Inc.- Prudhoe Bay~' API~: ,50029-20687-00 Well Type: Injector Completion Date: 02-2G82 New !~1 Workover r-I Hanger Type: Oct Hanger: 27' Maximum Hole Angle: 32~ Angle Through Sad.: Reference Log: BHCS 02-15-82 RKB Drilling MD to Top of Equipment except where noted. Jewelry. 10 1 2255' 2 8575' 3 85c~ 4 8688' 5 8701' 6 8702' 8692' 5-1/~" Cart~o Bal-O S~SV Nipple ID=4.562" Baker PBR Assembly Baker SAB Packer Camco DB-6 Landing Nipple ID--4.437" Baker Shear Out Sub Tubing Tall 5-1/2" ELM Tubing Tail: 11-06-82 Fish: Underreamer Pilot Bit (02-25-91 Minimum ID: Camco DB-6 Landing Nipple ID-4.437' Casing and Tubing 7 13-3/8" 72~ L-80 0 2659 Casing 2 8 9-5/8" 47f L-80 0 942~ Casing 3 5-1/2" 17# L-80 0 8702' PC Tubing 5~ Perforation Data (ELM Depths) Interval Zone FT SPF Date .~ 9145-9165 2 2D 0 07-07-90 CTU Squeeze ARC* 9184-9192 2 8 0 07-07-90 CTU Squeeze ARC* 9206z~32 2, lB" ~ 0 07-07-90 CTU Squeeze ARC* 924G9260 lB gO 4 08-16-90 Reperf 9270-9306 lB, lA 36 .4 08-16-90 Reperf 9~)-932[] lA 14 4 08-16-90 Apeff * Acid Resistant Cement 10 Cement Top @ 9366' ELM 08-12-90 PBTD = 9380' TD = 9440' Datum 8700' SS = 9228' MD 8800' SS = 9332' MD Revision Date: 03-01-92 byWDM Reason: Correct Completion Date Previous Revision: []3-[]4-91 Well 1i-7 Date: 7/7/92 RE: DS 11-07i Perf P&A LeoI We pumped 5 bbl neat Class 'G' and 49 bbl Class 'G' with aggregate. Estimate 28 bbl behind pipe and top of cement at 8700', which meets requirements. We built pressure to 1200 psi but it broke back to 500 psi, where it held. We jetted the tubing tail & jewelry during which the returns were 1 for 1. Dan 1. Typo of Request: OIL AND GAS CONSERVATION COMMIS~,',I APPLICATION FOR SUNDRY APPROVALS Abandon__ Suspend - 'f~ Operation Shutdown ~ Re-enter suspended well__ INAL Alter casing __ Repair well __ Plugging __ Change approved program __ Pull tubing __ Time extension Stimulate Variance Perforate__ Other x Pllugback for Sidetrack 2. Name of Operator ARCO Alaska, Inc. 3. Address Po O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 253' SNL, 81' WEL, SEC. 33, T11N, R15E, UM At top of productive interval 1514' NSL, 979' WEL, SEC. 28, T11N, R15E, UM At effective depth 1632' NSL, 1034' WEL, SEC. 28, T11N, R15E, UM At total depth 1649' NSL, 1041' WEL, SEC. 28, T11N, R15E, UM 12. Present well condition summary Total depth: measured true vertical 5. Type of Well: Development__ Exploratory StratJgraphic __ Service x REEElVED J UN 1 0 1992 Alaska 0il & Gas Cons. ~0m~tSsi0t~ Anchorage 6. Datum elevation (DF or KB) KBE = 62' feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number DS 11-07i 9. Permit number ~1.~-177 ~ rr,. 10. APl number 50- 029-20687 11. Field/Pool Prudhoe Bay Field/Oil Pool 9440 feet BKB 8967 feet Plugs (measured) Cement top @ 9366' (8/12/90) Effective depth: measured 9366 feet 'true vertical BKB 8895 feet Junk (measured) Casing Length Size Cemented Measured depth Structural Conductor 80' 20" 275 sx Permafrost II 80' Surface 2659' 13-3/8" 2700 sx Fondu/400 2659' Intermediate sx Permafrost "C" Production 9429' 9-5/8" 788 sx Class "G" 9429' Liner Perforation depth: measured 9240'-9260',9270'-9306',9145'-9165',9184'-9192',9206'-9232' True vertical depth 80' 2659' 8956' true vertical 8773'-8792',8802'-8837',8681'-8700',8719'-8727',8740'-8765' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 tubing to 8702' Packers and SSSV (type and measured depth) Baker SAB packer @ 8590', 5-1/2" Camco Bal-O SSSV Nipple @ 2255' 13. AttaChments Description summary of propOsal x Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 7/14/92 16. if proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil Gas Service Water Injector Suspended __ 17. I hereby certify tha! ~e fo~rego~,ng is true and correct to the best of my knowledge. Signed #I' ~(~' Title Drilling Engineer Supervisor FOR COMMISSION USE ONLY Conditions of approval: Notif~'"Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance ~ Mechanical Integrity Test ~ Subsequent form required 10- ~-~- ORIGINAL SIGNED BY Approved by order of the Commission LONNIE C. SMITH ,., ~o[iApproval No. 'Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Procedure Outline: (Refer to attached wellbore schematic) 1. Notify an AOGCC representative prior to commencing operations. 2. Rig up coiled tubing unit. 3. RIH with coil tubing circulating seawater. Cleanout to top of fish at 9145' WLM. Lay cement plug from 9145' up to packer at 8590'. Attempt to squeeze cement past fish into live perfs. 4. RU slickline unit. Tag cement to ensure that cement is at least 100' above highest holes seen in liner. (Highest hole at 9100' hence top of cement plug to be no deeper then 9000') Note: Tag to be witnessed by AOGCC representative. 5. RU E-line and make a tubing cut at +/-8560' MD based on completion tubing tally. 6. Circulate well over to seawater and freeze protect well to 2000'. 6. Bleed tubing, inner annulus, and outer annulus to 0 psi. 7. Set 5-1/2" BPV and prepare pad for rig arrival. RECEIVED J UN 1 0 1992 Alaska 0il & Gas Cons. Cornm|ssio~l Anchorage DS ~r ~7-ST Sundry Permit Inform~~ .~n Ob!ective: The primary objective the the 11-07-ST sidetrack is to return the well to water injection by drilling a new hole to a location near the current BHL in lieu of an extensive workover. Well 11-07 is currently shut-in with confirmed liner leaks and junk/fill in the wellbore above the desired Lower Romeo injection interval. A short sidetrack is preferable RWO options such as a scab liner to provide a mechanically reliable wellbore capable of reestablishing long-term Lower Romeo injection support. Procedure Outline: · . 3. 4. 5. 1 · 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. R/U Coil unit. Attempt to squeeze cement into perfs below junk/fill. Leave cement in wellbore at least 100' above top hole in liner. Cut tubing above the packer PBR. Freeze protect well. MIRU workover rig. Pull 5-1/2" BPV. Circulate diesel from well. Set two-way check valve. Remove the tree. Install and test BOP's. Pull two-way check valve. Pull the 5-1/2" 17# L-80 tubing completion. Run 9-5/8" casing corrosion log. Test 9-5/8" packoff in the FMC GEN-II wellhead to 3500 psi and replace if necessary. RIH with section mill. Spot a 17 ppg pill on bottom and cut 60'-80' from the 9-5/8" casing starting at 8270' MD. Set a cement kick-off plug from top of the tubing cut-off to 250' above top of the section. Run in the hole with a steerable, directional drilling assembly and dress off the plug to 8275' MD. Kickoff through the section and directionally drill to TD of 150' MD below the Base Sadlerochit at 8787' ss and about 250' departure east from the current wellbore at target depth of 8787' ss. Run wireline conveyed open hole (GR/DIL/CNL/BHCS)logs. Install and cement 7" L80 liner from TD to 250' above top of the section. Clean out liner to PBTD, displace well to inhibited, filtered seawater (if unable to displace cement with seawater and reverse out excess) and test to 3000 psi. RIH with 4-1/2" L80 completion assembly. Space out and land tubing hanger. Displace diesel down annulus and U-tube into tubing to freeze protect to a depth of 2000' MD. Set BPV. Remove BOP's. Replace tree and test to 5000 psi with diesel. Pull BPV. Drop packer setting ball and pressure up to set 7" L80 packer. Test tubing to 4000 psi. Test tubing x casing annulus to 3500 psi. Set BPV. Release rig. A CBL will be run over the 7" casing interval and the well perforated with wireline conveyed guns after the rig has moved off of location. Anticipated BHP: 8.1 ppg equiv. Drilling Fluid: 9.5 ppg Workover Fluid: 8.5 ppg. RECEIVED J UN 1 0 1992 Alaska 0il & Gas Cons. Comm'tss'tot~ Anchorage _ _ i i iii i ii i ii ii i i i ii ii i i lmm I ~ I il iml I / / ,,,.. RECEIV T) Alaska Oil & Gas Cons. Bom~tss'to~ Well 11-7 Spud Date: 01-31-82 C~riginal RKBE: 62" p of Sadlerochit: 8&52' Annulus Ruid: Diesel/9.8# NaCI Reference Log: BHCS 02-15-82 All are RKB Drilling MD to Top of Equipment except where noted. Alaska Inc.- Prudhoe B~ ~''~,ld API~: ~20687-00 ~ ~,~ell Type: Injector Completion Date: 02-20-82 New [] Workover r-1 Hanger Type: Oct Hanger: 27" Maximum Hole Angle: 32-~ Angle Through Sad.' 17-~ 5-1/2' Camco Bal-O SSSV Nipple ID=4.562" Baker PBR Assembly Baker SAB Packer Camco DB-6 Landing Nipple ID--4.437" Baker Shear Out Sub Tubing Tall 5-1/2" ELM Tubing Tail: 11-06-82 Fish: Underreamer Pilot Bit (02-25-91) Jewelry 1 2255' 2 8575' 3 859Er 4 8688' 5 8701" 6 8702" 8692' 10 Minimum ID: Camco DB-6 Landing Nipple ID--4.437" Casing and Tubing ~zJZ,~ ~ Grade ~ Bottom 7 13-3/8" 72# L-80 0 2659' Casing 8 9-5/8" 47# L-80 0 942~ Casing 5-1/2" 17# L-80 0 8702 PC Tubing 5~ Perforation Data (ELM Depths) Interval ~ FT SPF Date Comments 9145-9165 2 20 0 07-07-90 CTU Squeeze ARC* 9184-9192 2 8 0 07-07-90 CTU Squeeze ARC* 9'2[]6-9232 2, lB 95 0 07-07-90 CTU Squeeze ARC* 9240-9260 lB 20 4 08-16-90 Reperf 9270-9306 lB, lA 36 4 08-16-90 Reperf 930~9320 lA 14 4 08-16-90 Aperf * Acid Resistant Cement R[¢EIVtD I. ] J UN 1 0 199 10 Cement Top @ 9366' ELM 08-12-90 Alask[~ Oil & 6as Gon$, Anchorage PBTD = 938[7 TD= 9440" Datum 87[]0' SS = 9228' MD 8800' SS = 9332' MD Revision Date: 03-01-92 byWDM Reason: Correct Completion Date Previous Revision: 03-04-91 Well 11-7, ARCO AI_AZKA, :[NIB. F', 0. B(]X ~ ,::;, (!:, .:~ 6 (i:, ANCHORAGE, ALA,'~K A RECEIVED DATE RiEFERENCE · ARCO CASED HOLE SEP 2 6 19.g3 AlasKa Oil & Gas Cons. Commission Anchorage 2 - i i 8 - :3 i --- 9 ,q T I E- i N / E-L t .~.,i ,':' p L l i G F: i i i'--.~ '~ '=:'-" S'-2 8-26-9'?:: F'RODUC:T:[ON F'R!]F.ELF' RUN i , 5" .... ~.:, E;: f~j i::' i r.;' .--:: a .5-:3 q- '::' ":' - ?,':~ F'RF~DLJC'T I ON .....T,_,_ F.'i iN '~, '.~- ,i :3 8-- 22--' ?' ;:" 'r ~-.~ ~1: C T 'r 0 N F' i:;' 0 i:' I ~ ~:' F' t ~,,i ~ 5" -z, _.-..', ,:::, :-q--22-9;:" F'IRF)T",i ~ .... L.'" T I OJ"~ i::,i:',F'lr-'r~ c:' ,'i:' T ;",. ,~.'?" RUN' i , '=" '~ : ..... .. .... *.**- .. I 1%. -. t .L I.. L. :' ,J. ..,." ~'~ "-'*" '**'*" 9 '- :5 9'*:; *,- c: :***~ ~:, i;, I Ihi~ 5" , :._ ...- '~ .-. i i..i ii ~ .... -.~., ...... ~- ..... , ', ~.- ,.,. 'r ~' I'] i'.,i I:;..' U N i , ';" :' 5'- ~ 'i 8-'3 i -9':'::' br..' ~,URR,:.I_,--~, .,.' ....... . 6-24 ~..'"."-'~, 5-9':.'} COLLAR/F'ER.F RUN 'i ,5" ?-?;,5 "?-8-":.:"('} .......... F' T TS F.'~ iN ~, _,"-"'" 9-4'i 9'"-' ,i ;:',.-o,'.~, PEF-'.F I:;,~:F'F~.r,,r', Pi tKI~ , ~.-.'" 9-43 9-'i 5..-"T."(') (.";OLLAR/PEF,'.'.F f;..'LJi'-~: ~ , 5" ~ 'i - ? 8 -'27 - 9 ,':', ! N J E C T T F'~ N i:. ~:, ~'] ~-- ! L F ~;' ~ I ~..~ '2 ~"" t ...o .b .. . ~ i · .~: t · -,~ t .. i --*.:' 'i 'i '-- ~ 88-' 2 7 "-' 9,:-} P R 0 D U C: Z-" ]: 0 N P R 0 F ]: L ~'.: R U N '! ,:3" ~:_'~- ".:',_ A.. ,::,"" "- ""..:, ~' "--':-~, ~._. C- R C ~ F..' R E L A "F :[ 0 N s:'U ..... N ~., ~;.," 'i 4 -- 5 ~ :q - 9 '7 - 9 ,:i)F' ~::' 0 D U C: 'f' ]: 0 i'".i F:' R 0 F' :[ ~ ..c R ~ 1Ni "'-" .. ,%o . . = -. . ~.. i. .... ; ,..-' F._I:.H,:~ L:I(;N AND RETURN THE ATTACHED COF'Y A.",3' R.F_.:CEIF'T OF DATA HAVE A NIC'E DAY! 2AL. L.Y u ;"~ r': r: c' r' L' [':. R I t1.. t t !.# A T O -- 'i ''"' '" ...-' .-:.: '2 tS ~::'~ f'i I...: U. C: A ~'~ C '] F" .'":', i"4 F'-F'~ · ..~ i",, i -".... ~...~ C ...'::',, :'fi C ~.3 F: F':: i'.-'i C ~'.] ,.--...o .: ......... :.... '.:.:i l:'l L: !':.: ::>,. i'~ !::.': 0 A T i.. A ,S ........ i-i i-:: 3' A T L. A Z.~' (3.: A ['i C 0 C A fi.' C 0 CAMCO C A M C 0 D i £' T R :!: B U T ]: 0 N -"- CENTRAL FILES · "' FtHFVRON D & M · ,-'"' EXTENSION EXF. LURATION. ,...,. ,.,. · "'EX,,,ON MARATHON ~ MOBIL '"' F' !,-t :[ L L I F' ~:' i:'B WEI_L F:!:LE:3' R & :C:, '""' B I::'X 'II° '"' ."~]"ATE OF' ALA'""KA TEXACO ~, =.:,.:~ _ ,:.) 2 o _ ..-~ (:) c;, o; :~.. THE CF)Rr':'F'rCTED. . · .... AF't~ F'OF;,' 4-')'::),_. .,,.T,~. -.-., ; ::../, ;,_,,. :~':'~ 'THE CORRF:CTED AF'i:,$ FOR '?-S:5 I:£ ~':;~:'"-;"';'::'"-'-"'~i809 .... o..,. °.~ ..., ~._ / .. STATE OF ALASKA ALASKA(' .. AND GAS CONSERVATION C(~, ,,IlSSION · REPORT F SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing .... Alter casing Repair well 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development X Exploratory ...... StratJgraphic 4. Location of well at surface 253' FNL, 81' FEL, Sec. 33, T11N, R15E, UM At top of productive interval 1514' FSL, 979' FEL, Sec. 28, T11N, R15E, UM At effective depth At total depth 1649' FSL, 1041' FEL, Sec. 28, T11 N, R15E, UM 12. Present well condition summary Total depth: measured true vertical 9440 feet Plugs(measured) 8967 feet Perforate.~.[~ I I3 I N ~ l Other X 6. Datum of elevation(DF or KB) 62 RKB 7. Unit or Property Prudhoe Bay Unit feet 8. Well number 11-7i 9. Permit number/approval number 81-177/90-069 10. APl number 50 - 029-20687 11. Field/Pool Prudhoe Bay Oil Pool Effective depth: measured 9380 feet true vertical 8909 feet Junk(measured) Casing Length Size Cemented Conductor 80' 20" 275 sx PF II Surface 2597' 13-3/8" 2700 sx Fondu & 400 sx PF 'C' Production 9367' 9-5/8" 788 sx CI 'G' Measured depth True vertical depth 80' 80' 2659' 2659' 9429' 8956' Perforation depth: measured 9240-9260'; 9270-9306'; 9306-9320' true vertical 8773-8792'; 8802-8837'; 8837-8850' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 8702' MD Packers and SSSV (type and measured depth) Baker SAR packer @ 8590' MD; 5-1/2", Camco Bal-0 SSSV @ 2255' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached Treatment description including volumes used and final pressure 14. Re0resentative Daily Averaoe Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation .... 23168 -- 1351 Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations -- 10532 -- 1479 16, Status of well classification as: Oil___ Gas Suspended__ Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 545 REK c: J. Gruber, ATO-1478 SH DS 11-07i ~' DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE · INJECTION PROFILE MODIFICATION 5129190: MIRU CTU & Stimulation equipment. PT equipment to 4000 psi. RIH w/CT, and washed perforations at: 9145 - 9165' MD Ref. Log: BHCS 2/15/82. 9184 - 9192' MD 9206 - 9232' MD 9240 - 9260' MD 9270 - 9306' MD Pumped: 59 bbls 12% HCI w/10% Xylene, followed by, 59 bbls 12-3% HCI-HF, followed by, 24 bbls 6% HCI, followed by, 120 bbls 2% NH4CL w/suractant, followed by 3 bbls Diesel & 30 bbls Meth Water flush. POOH. RD. 6/2190: A CTU Squeeze was performed as follows: MIRU CT & Cementing Equipment. PT equipment to 4000 psi. RIH w/CT and fluid packed wellbore w/490 bbls of seawater. Pumped 178 bbls of cement, squeezing perforations at: 9145 - 9165' MD Ref. Log: BHCS 2/15/82. 9184 - 9192' MD 9206 - 9232' MD 9240 - 9260' MD 9270 - 9306' MD Placed 160 bbls of cement behind pipe, at 1500 psi maximum squeeze pressure. Contaminated cement w/Biozan, and cleaned cement from wellbore. POOH. RD. 6/10/90.' Injectivity test indicated squeeze broke down. 7~7/90: A CTU Resqueeze was performed as follows: MIRU CT & Cementing Equipment. PT equipment to 4000 psi. RIH w/CT and fluid packed wellbore w/501 bbls of seawater. Pumped 86.5 bbls of cement, resqueezing perforations at: 9145 - 9165' MD Ref. Log: BHCS 2/15/82. 9184 - 9192' MD 9206 - 9232' MD 9240 - 9260' MD 9270 - 9306' MD Placed 67 bbls of cement behind pipe, at 1300 psi maximum squeeze pressure. Contaminated cement w/Biozan, and cleaned cement from wellbore. A cement plug to 9100' MD was left in the well. POOH. RD. 7/11/90 - 8/14/90: Underreamed cement to 9366' MD. 8/1 6/90: Reperforated: 9240 - 9260' MD 9270 - 9306' MD Ref. Log: BHCS 2/15/82. Added perforations: 9306 - 9320' MD Ref. Log: BHCS 2/15/82. Plans to stimulate the well following reperforating were cancelled. The well was returned to injection and a valid injection test was obtained. A F;,' C 0 " mL.~b. K A., F',O, BOX i ANCHORAGE, ALASKA 995i~ DATE- 8-28-90 REFERENCE- ARCO CA£ED HOLE FINALS ¢'!_; ,.., ,. ,., LEAK DE ¢ i -o, 8-i _o,.~, .. PRODUCT ¢ i -t ¢, 8-5-9E~ PRODUCT ~ i -i 2 8--4-9~ LEAK DE ~i '-2~ 8-4-9¢ PRODUCT ¢2-29A 8-5-96, PRODUCT ~-.~ ~, 8- t COLLAR/ ¢ ~ - o 4 ~ - -Z ~? - 9 ,.~ C 0 L L A R / ¢--5 4 8- i 7-9,1~ COLLAR/ ¢9-4i 8-t 7-96, PERF RE ~9-42 8-i 8-9¢ GR-CCL ~9-42 8-i 8-96, PERF RE ¢'i 'i -7 8- i 6-9~ COLLAR/ ¢3--t 8-'~ ' -~¢~ ~1 "~ COLLAR ¢ S-i 8-2i -99 VERT]:LO ,.-5 _ . , PRODU~I ¢'~ 4-t 5 8-25-9~ ¢ 5- t t 8-2-96, TECTION/PROD PROFILE :[ON PROFILE ION PROFILE TECTION ION PROFILE ION PROFILE PERF PERF PERF CORD JEWELRY CORD PERF ION PROFILE COLLAR/F'ERF DATAFRAC SURVEY TEMP DECAY DIAGNO~'¥IC FM RIIN_ i., _.~'" RUN I, 5' RUN i , ~ ' RUN i, 5' RJN i, 5' RUN i , 5:' RUN ~, 5' RUN i , 5:' RUN t, 5' RUN i , .,s- RUN ~, 5' RUN i , 5:' RUN t, 5' RUN i, 5" RUN i, .,'s' RUN t, 5' RUN i, 5" R~JN t 5" RUN t, 2".:,.,~ ~' F'I_EA3E £.'IGN AND RETURN ]'HE ATTA.,HED COPY HAYE A NICE DAY! S~P-5~0 A~ RECEIPT OF DATA~ APPROVED 'trRAN~'~ 9r~ CAMCO CAMCO CAMCO CA~"~CO CAMCO CAMCO A'f'LA~' ATLA~ A'f'LAS' $CH ~,H $CH ATLAS ATLA3 ATLAS' CAMCO A'I'L A i,' CAMCO CAMCO CAMCO DISTRIBUTION CENTRAL FILES CHEVRON EXTENSION EXPLORATION EXXON MARATHON MOBIL PHILLIPS F'B WELL FILES' R & D BF'X STATE OFALASK" A .,. ... TEXACO ARCO ALASKA, INC~ F'~O. BOX i00360 ANCHORAGE, ALASKA 995i0 DATE' 6/iS/90 REFEREN.,E ARCO CASED HOLE FINALS' 2-t 5-23-90 PRODUCTION F'ROFILE RUN ":'-"~i 5'-2:.3--90 PRODUCTION PROFILE RUN ~ 5" .c"-""8. 5-28-90 TEHF'ERATURE ~'UR. VEY RUN 4-~ ,:.-~ 5-26-90 INJECTION F'ROFII_E RUN 4--32 5-':2'?--90 TEMPERATUR. E LOG RUN i , 5" i i -7 ~_.-.,z._of.-, INJECTION F'ROFILE RUN i ~':' i i -i 6 "'~--':~2-c;',:".,F'RODUCTiON F'ROFILE RUN ~ ~:" t~-~7 5-22-90 PRODUCTION PROFILE RUN ~.=°-33 5-25-9,?) COI. LAR RUN I:'I..EA.~TE .~:[GN AN):) RETURN 'THE ATTACHED COF'Y AZ RECE!'~"¥ OF DATA. RECE I VF.:I) BY ...... ~~~.~'~::ZL__ HAVE A NICE DAY! SALLY HOFFECKER A TO- ~ 529 RECEIVED 'i"RAN$¢- 9022 i 1990 R~(]l!l~.,t,~'-' · "' .EN I RAL FILE~ ,,'~ CHEVRON D & M ~,. E,,,'[E.N,, IUN EXPLORATION · ,- EXXON N A R A T H 0 N ~ M 0 B I L PH II_L I'"'"' PB WE:LL FIL. E:S' R &.D · .' B F:' X ¢- STA'I'E OF ALAS'KA TEXACO ,~RCO Alaska, In~~ Post Office%..,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4274 Robert Iden Engineering Manager Prudhoe Bay Field February 1, 1990 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 11-7, Permit No. 81-177 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Sincerely, D. F. Scheve DFS/REK/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 11-7)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6057-E STATE OF ALASKA ALASI~'~ LAND GAS CONSERVATION APPROVAL, APPLIC -, I'ION FOH UNDHY 1. Type of Request: 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 Abandon---- Suspend ~ Operation shutdown Alter casing Repair well~ Plugging ~ Change approved program Pull tubing Variance 5. Type of Well Development :X Exploratory Stratigraphic Service 4. Location of well at surface 253' FNL, 81' FEL, Sec. 33, T11N, R15E, UM At top of productive interval 1514' FSL, 979' FEL, Sec. 28, T11N, R15E, UM At effective depth At total depth 1649' FSL, 1041' FEL, Sec. 28, T11N, R15E, UM Re-enter suspended well ~ Time extension Stimulate ~X Perforate X Other X 6. Datum of elevation(DF or KB) 62 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 11-7 9. Permit number 81-177 10. APl number 50 - 029-20687 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9440 feet Plugs(measured) 8967 feet Effective depth: measured 9380 feet true vertical 8909 feet Junk(measured) Casing Length Size Cemented Conductor 80' 20" 275 sx PF II Surface 2597' 13-3/8" 2700 sx Fondu & 400. sx PF 'C' Production 9367' 9-5/8" 788 sx CI 'G' Measured depth True veHicaldepth 80' 80' 2659' 2659' 9429' 8956' Perforation depth: measured 9145-9165'; 9184-9192'; 9206-9232'; 9240-9260'; 9270-9306' true vertical 8681-8700'; 8719-8727'; 8740-8765'; 8773-8792'; 8802-8837' ,, ..~,~ ,8, ~:~,~:ls~'-'" Cons. ~¢~,,'~'~,,~ Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 8702' MD Anohor~3 ~ Packers and SSSV (type' and measured depth) Baker SAB packer @ 8590' MD; 5-1/2", Camco Bal-0 SSSV @ 2255' MD 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation February 1990 16. If proposal was verbally approved Oil Name of approver Date approved Service 17. I hereby.certify that the foregoing is true and correct to the best of my knowledge. Signed ~/~¢',~/~ Title 15. Status of well classification as: Gas ~ Suspended Injector Operations Engineering Manager FoR COMM~ION U~r: ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- J_~ L) Date /~'~/~'~ Approved by order of the Commissioner Form 10-403 Rev 06/15/88 285 R. E. Krause ORiGiNAL SIGNED BY Commissioner SUBMIT IN TRIPLICATE Well 11-07i Coiled Tubing Unit Cement Squeeze Project AFE #AP6168 Preliminary Procedure Objective: Perform a CTU cement squeeze to shut off a channel to an Upper Victor injection thief and establish injection into the Lower Romeo. 1. Perform a FCO to establish sufficient rathole below the lowest set of perfs. 2. Perform a Water Injection Profile. 3. Perform a full strength mud acid perforation wash treatment. The perforations will be washed using coiled tubing to pump the following: 5000 gallons HCl/Xylene 2500 gallons Mud Acid 2500 gallons 7.5% HCl 4. RIH with CT. Pack the well with filtered seawater. 5. Pump 100 bbls of cement followed by 5 bbls of fresh water. Squeeze off the following perforations: Zone Present Interval Shot Density 2 91 45-91 65 4 SPF 2 91 84-91 92 4 SPF 2,1B 9206-9232 4 SPF lB 9240-9260 4 SPF lB,lA 9270-9306 4 SPF 6. Pump 200 bbls of contaminant following the fresh water and dilute the cement in the wellbore. 7. Jet or reverse out the contaminated cement 24 hours later. 8. Reperforate the following interval two weeks later: Zone Proposed Interval Shot Density 1 B 9240-9260 FSD REPERF 1 B, 1 A 92 70 - 9306 FSD REPERF lA *9306-9336 FSD ADPERF * These intervals are currently out for Co-owner approval but are expected to be approved before the time of perforation. 9. Evaluate injectivity into Romeo. Pedorm Romeo only stimulation/biocide as per attached procedure. 10. Perform post stimulation Water Injection Profile. Evaluate injectivity into Romeo. 11. Reperforate Tango and Upper Romeo intervals: (Ref: BHCS 2/25/78) Zo~ Prooosed Interval ~hot Density 2 91 4 5- 91 6 5 LSD REPERF 2 91 8 4 - 91 9 2 LSD REPERF 2,1 B 9206-9232 LSD REPERF 12. Put the well back on injection. Other well information: Current status: On produced water injection--33 MBWPD at 1785 psig ITP. Expected static bottomhole pressure: 3680 psi at 8800' SS Expected fluid in wellbore at reperforation: seawater. RECEIVED FEB O~'~,~ l~x~/'',~ , ,.,..~,.,~.~ OiJ & ~as Cons. Anch0ra~e Drill Site 11-7i Lower Romeo Selective Matrix Stimulation ARCO Alaska, Inc. proposes to perform the following stimulation treatment: 1. If fill is above 9306' MD then perform a nitrified FCO. 2. Load the following fluids: a. 9000 gals. of 12% HCl acid with additives. b. 7500 gals. of 6% HC1:1.5% HF with additives c. 9000 gals of 3% HCl with additives d. 7500 gal 5% HOOH (hydrogen peroxide) in 4% NaCl water e. 10000 gals of 2% NaCl f. 6000 gals of 2% NaCl gelled with 50 Ibs/Mgal HEC and 3000 lbs BAF g. 500 gal xylene h. 100 bbl methanol 3. MIRU CTU. Rig up CT with 4-1/8" x 9-5/8" packer and tubing end Iocator. 4. RIH with CT. Locate tubing tail using the tie-in log. Locate and inflate the packer element at 9200'MD. 5. MIRU transports and pump trucks. 6. Pump the following fluids down the coiled tubing to stimulate the Lower Romeo interval (9240' to 9326'MD): a. 500 gal xylene b. 1500 gal 12% HCl with additives to clean the CT c. 2000 gal gelled 2% NaCl with BAF e. 2000 gal 2% NaCl f. 2500 gal 5% HOOH g. 1 Coiled Tubing Volume (24 or 32 bbl) of 2% NaCl h. Shut down for 3 hours i. 750 gal 2% NaCl with BAF j. 2500 gal 12% HCl with additives k. 2500 gal 6% HC1:1.5% HF with additives I. 3000 gal 3% HCl with additives m 1000 gal gelled 2% NaCl with BAF I 2000 gal 2% NaCl n. 2500 gal 5% HOOH o. 1 Coiled Tubing Volume (24 or 32 bbl) of 2% NaCl p. Shut down for 3 hours q. 750 gal 2% NaCl with BAF r. 2500 gal 12% HCl with additives s 2500 gal 6% HC1:1.5% HF with additives t. 3000 gal 3% HCl with additives u 750 gal gelled 2% NaCl with BAF v 1500 gal 2% NaCl w. 2500 gal 5% HOOH x I Coiled Tubing Volume (24 or 32 bbl) of 2% NaCl y. Shut down for 3 hours z 500 gal gelled 2°/0 NaCI with BAF aa. 2500 gal 12% HCI with additives bb. 2500 gal 6% HC1:21.5% HF with additives cc. 3000 gal 3% HCI with additives dd. 2000 gal warm Methanol (75 deg F) to dissolve BAF 7. POOH with CT. Pump remaining 2% NaCl and freeze protect, ::':?; 8. RD and release CTU, pump truck and transports ,~ Reference Log BHCS 2/15/82 6 4 3 2 COILED TUBI, Nt~ UNIT BOP EI)U ! PHENT 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE: 2. 5000 PSI 4 1/16" PIPE RAHS 3. 5000 PSI 4 1/6" I"IYD~L~ SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAHS 6. 5000 PSI 4 1/16" STUFFING BOX 2 H]REL INE i BOP EOU ] PHENT 1. 5000 PSI ?" WELLHEAD CONNEOIOR FLANGE 2. 5000 PSI WIRELINE RAIDS (VARIABLE: 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF' ARCO ALASKA, INC. F'.O. BOX i00360 ANCHORAGE, ALASKA 995't0 DATE' 8-29-89 REFERENCE' ARCO PRESSURE DATA 3-t 5 7-.27-89 BHF'--$TATIC GRADIENT CAMCO 3-33 7-14-89 BHF'--$TATIC GRADIENT CAMCO 4-2 7-8-89 BHF'--$TATIC GRADIENT (W/ATTACH.) CAMCO 7-5 ?-~9-89 BHP--$TATIC GRADIENT CAMCO 7-7A 7-3~ -89 BHF ....PBU HR$ 7-8 '7-29-89 BHF'--$TATIC GRADIENT CAMCO 7-t0 8-5-89 BHP--~'TATIC GRADIENT CAMCO 7-t 4 '7-29-89 BHP--PBU HR$ 7-27 7-23-89 BHP--$TATIC GRADIENT CAMCO '?-33 7-23-89 BHF ....STATIC GRADIENT CAMCO 9-24 7/~4-t5/89 BHP--~'TATIC GRADIENT CAMCO 9-38 8-t ~-89 BHP--~'¥ATIC GRADIENT CAMCO t t -'~ - ~. 7-7 89 BHP--$TATIC GRADIENT HR,S' ft-7 '?-9-89 BHF'--$TATIC GRADIENT HR$ tt ~6 7-t0-89 BHF'--$TATIC GRADIENT HR$ ~-f7 8-tJ-89 BHP--FLOWING GRADIENT CAMCO ~ 2-3'0 7-23-89 BHF'--$TATIC GRADIENT CAHCO f4'-f9 8-t 0-89 BHP--$TATIC GRADIENT CAMCO ~4-22 8-~7-89 BHP--$TAI'IC GRADIENT CAMCO t 4-36 7-29-89 BHP--FLOWING GRADIENT CAHCO f 4-39 8-~ 3-89 BHP--$'TATIC GRADIENT CAMCO ~5-t~ 7-2t -89 BHF'--$TATIC GRADIENT CAMCO t 6'-1 2., 7-26-89 BHP--$'TATIC GRADIENT CAHCO t 6-20 7--t 3-89 BHP'~$TATIC GRADIENT CAMCO t 8-25 7-'t 3-89 BHP--3'TATIC GRADIENT CAMCO F'LEA~E £IGN AND RETURN THE ATTACHED COF'Y AS RECEIPT OF DATA DI~'TRIBUI'ION CENTRAL FILES CHEVRON "- D & M EXTENSION EXPLORAI'ION .~ EXXON MARATHON /2. ~ MOBIL ~' F'HILLIF'5' F'B WELL FILES -"- R & g ~ BF'X .~ STATE OF ALASKA ~,~ TEXACO ARCO ALA21<A, fl.'NC· f:'~O. BOX ~e(')360 ANCHORAGE, ALA2KA- 995 i 0 /1 DAI'E: 7-t 7-89 REFERENCE: ARCO CASED HOLE FINALS S-'i~ 6-29-89 SF'INNER SURVEY 3-t 2 6-29-'89 3'F'INNER 3'tJRVEY 3-i5 7-7-89 I'EHF' SURVEY 3-22 7-9-89 'f'EHF' StJRVEY 5-'3 '7-t '-89 TEHF' 3'URVE:Y 9-'2 7-5-89 TEMF' $~JRVEY 9-'6 7-5-89 I'EMF' SLJRVE:Y 9-7 7-5-89 'I"E MF'StJRVEY 9-9 '?-'5-89 I'EMF' SUI:~VEY 9-28 7-5-89 TEHI:' StJRVEY i i-'2 7-7-89 I'EHF' ,";LJRVE:Y ii-7 7-9-89 TEHF' SURVEY i i .... i6 7'"i0-89 I'EHF:' SLJRVEY .....~ 25 6-3e-'8~ '[EMI:' ~'IJRVFY i 2-25 6-.3e-89 SF:'INNIFR 3'LJRVEY t 6.-20 "/'-8-.89 TEHF' ;S'IJRVEY RLJN i , 5' RUN RLJN t , ':.>" NUN t, '5" RLJN i, 5' RUN i RLJN i, 5" RLJN RUN I, 5" RUN f, 5" RUN i, '2"&5" RUN RUN t, 2'&5" RUN t , 5" RUN R~J N ~, '5" F'I.F'ASE 3'IGN AND REI'URN I"HE A'¥TACHED COF'Y A2 RECE:IF'T OF DA RECEIVED BY HAVE A NICE DAY! SALLY HOF'FECKER AT0-i529 .. I)I,S'TRIBUTION '"' F' · ,,.HILI..IF'$ F'B WELL. F'I:LE$ R & D .-"'BF'X · ,,.'"' STATE OF ALASKA ~~ TEXACO 0 TI 2 0 T I $ CJ'l' 1 .'; 0 1'13' O'F 13' 0'!' i S 01'I 3' O'r I $ OT I,S' o'r I $ O1"I 5' OTI3' O'1' I,~,' O 1" I $ O'1[':[$ DATE: 3-2-89 REFERENCE: ARCO CASED HOLE FINALS 3-t2 .~-~t-89~ PRODUCTION PACKER RUN t, 5" 4-2 2-tG-89 PRODUCTION PROFILE RUN t, 5' 4-t2 2-tt-89 PRODUCTION PROFILE RUN tt-2 2-3-89 INJECTION PROFILE RUN t, 5" tt-3 2-t-89 F'RODUCTION PROFILE RUN t. 5" tt-3 2-2-89 TEMP £URYEY RUN t, 2'&5" ~t-4 ~ ~ ~-~-89 PRODUCTION PROFILE RUN t, 5' ti-5 2-6-89 PRODUCTION PROFILE RUN ii-? 2-~-89 INJECTION PROFILE RUN ti-t2 2-3-89 TEMP SURVEY RUN t, 2' ti-iD 2-2-89 TEMF' SURVEY RUN t, 2" i2-3t 2-i7-89 CBT RUN t, 5' t2-~i 2-t7-89 CET RUN t, t4-i8 2-22-89 CNL-GAMMA RUN t, 5" t4-i9 ~°-~-89~ CNL-GAMMA RUN t, 5" t4-28 2~5-89 TEMP RUN t, 5' ~4-29 2-22-89 CNL-GAMMA RUN t4-3J 2-22-89 CNL-GAMMA RUN t5-°~ t-23-89 PRODUCTION PROFILE RUN t, 5' t8-4 2-i2-89 PRODUCTION PROFILE RUN t, i8-t7 2-i3-89 PRODUCTION PROFILE RUN i, 5' . PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA. RECEIVED HAVE A NICE DAY! SALLY HOFFECKER AT0-t529 TRANS APPROVED .... DISTRIBUTION ATLAS CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO $CH $CH ATLAS ATLAS CAMCO ATLAS ATLAS CAMCO CAMCO CAMCO ~ CENTRAL FILER. ~ PHILLIPS . CHEVRON PB WELL FILES D &M R& D ~ EXTEND I ON EXPLORAT I ON ~ SAF'C ~ EXXON ~ STATE OF ALASKA 1' MARATHON ~ TEXACO ~ MOBIL NOt'41J ARCO Ala.skm, Inc. F',O, E;ox ~(-)~560 Anr:hormge, A I. mska 99.5i 0 I)~TE: REF:'EF,:ENCE: ARCO Cased Hol. e Filnal. Miscible. [,e.~' .Tnj~,c'l'ion Profile Run Produ. c'l.- ion F.'rofi I.e/6R/FL. I:;~u'n i., Inject'ion F:'r'ofi [e Run t, !5" I~jection F'rofi I.e Ru.l~ t, 5" Product ion Profi I.¢.., Run Leak l)etec t i on/FH/l'emp ~ E'. u.l~ M, I ... .11 n j e c t i o n F' r o f i I.r...: R u n H i .s' c i b !. e (; ~ ,,.;' I n j e c ~. i o n F:'r o f i I. e Iq' u n Run t , 5" Ru.n 0-.9, t0-.87 I)ai',~fr~c/I-.Ioist' 0-. t 4--~ 7 F:' u. m ir, I n 1' e m p ,. / (; I:i: [.'.ar0c o Camco ['. m rn r.: o (".amc o Camco Camco, f.~ a m c r.-., C a m c o (.'; 8 r0 C~ 0 " (., 8 m ... o F'l.'em.¢e sign and / R e c o r d s' F'r o c e s_...s ~ ..... Oil & Gas Cons, Commission ~ T O- ~ 529 ~ Anchorage Trans ~:87592 Ap p r ov~)d ret'urn She at'tac:h.P.d copy ms rt-~c. Pip'l' of dm'i'e., D I X 'r R I B L.I'T '[ 0 N '"' F'h i I I. i p s' ~ (.';ent:ra I. F:'i I es ,,. ,.'"'Chevron F'B We I. [ F'i I.e.r, I) & Fi R & P ,f,.o i · ,.'"' [~; × t' ¢.,'ri..q'. J c','rl Fixp I.o'r' ~ i' Jot'; .,,.'"' ....AF't'... ~ Exxor, -f,: ,.?~.a~.e c.',f Al. aska Hara '!' h on ,-'" Texaco ~' Hob i I ARCO Alaska, Inc F'.O. Box Anchorage, Alaska 99~ DATE: August REFERENCE: 9-29 8-t3-87 t t -7 8-'] 4-87 PLease sign and ARCO Cased HoLe Final · return the attached Run t, 5' CoPY as receipt of data, Received By .... HAVE A NICE DAY! Rosanne F'eek Al'O-'t "") TRANS ~8743(') i~ Ar.) p roved. ........... .~.~ ......................................... DISTRIBUTION ~ CentraL Fi Les ~: Chevron D&M · ..'"' E x t' e n s' i o n E x p I. o r a t i o r, ~' Ex xon Hara thon :g: ['lob i L '~- F'hi LLips F'B WeLt Fi Les R & I) ~' Sob i o · "'-.. State of ALaska · ..'"' Texaco Sch $ch ARCO A'.aska, Inc· F'.O· Box t0036(~ Anchorage, ALaska 995ie DATE- duly 29,i9 86 REFERENCE' ARCO Cased Hole FinaL .- te 7-~4-86 Post $,~uee:e ~emp CCL Run 4-3 7-5-86 Product ion F'rofi [e Run ~ 5' 4-24 4-5-86 ACBLog/VDL/~ign/GR Run ~ 5" 4-38 7-~/~-86~ ~pinner [oq. Run 4-3~ 7-~/~-86 F'roduc~ion F'rofi Le Run ~ 5" 6-4 6-~5-86 Epi Log/LAC Run 2 5' 6-9 6-~ 6-86 Ep i Log/LAC Run 2 _, 6-J5 7-~6-86 ~pinner Temp Run J 5" 9-~, 6-7-86 PDK-J 08 Run J~-7 7-J6-86 Temp Log Run ~ 5' J3-29 7-~4-86 FLuid DensiCy Temp ~urvey Run · -~ Run J 5 J~-~ 7 ,-86 F'roduc¢ion Profi Le ' J7-3 7-~3-86 Pump io Temp Survey Run ~ 5' C8 il'lc o Ca l~ic: o Dress C~ mc o 68 mc 0 Dress Dre~ C~ mc o Dre~ Co mc o Co mc o Camco PLease sign and return the a~tached copy as ~-eceipt of data. Received By HAVE A NICE DAY! Linda HuLce ATO-i~g~, TRAN:?. '-064;7 l' '--' ~ '-.' DISTRibUTiONs, · ,,.'"- F'hiLLip~ F'B WeLL Fi Les R & D '"..,.- '¢'oh,--. i o · . ..... -~$e of Alaska · ,-- T~x.aco /kl~sk~ Oil & G~s Oons. Oommi~ ARCO Ataska, i~.c. F'.O. Box 100360 Anchorage, Alaska DATE' August t, t986 REFERENCE' ARCO Cased Hole Final 4-4 7-5-86 Production F'rofi [e Run ~ 5' ~4-32 7-9/t0-86 2pi'nner~"og Ru'.c ~ .~-" 9-9 7-23-86 F'u~,~pin Ten~p Survey Run t 9-35 7-23-86 F'umpin Temp. ~urvey Run ~-7 7-7-86 Injec$ion. Profi Le Log Run ~5-4 7-~ ~-86 ~p i ~ner ~urvey Run ~8-5 7-24-86 Gamma Ray Run C8 file 0 Ca ~i _no Camco Camco Camco Ca f~lC 0 Ca;~co PLease ~ign and return ~he attached copy as receipt of data. Received By__ HAVE A NICE DAY! Lioda Hu[ce AT0-t529 TRAN$ $86478 DItTRi~H~ION..~ , Centrat Fi Les Chevron D & M Ex+.en£ i on Exp [ora~ ior~ Ex xon Marathon Nob i [ ~iaska Oil & Gas ~ns. CommiSSio DATIii]' Ja'nu.a'ry i6, R E F" f:i '"' N C E ' .~", E A R C 0 i °°6 P ~- e .'...:: :~:,' u. 'r e D a l' a P I. e a ..:.~: e :~: ) g 'n a 'nd ~" e i: u 'r 'n i' h e a i' .i: a ,::: h e,::i ,::: c, t::' ¥ a ..~: 'r e c e i i::' '!' o I'" d a i' a., i::,,., (.:.:, C (a i' 'v' e ,.':I B '::." .................................................................................. H A V J..i: A i"-.! I C: Iii; D A Y ! D :[ :'!':; '",;' R ! B U T :[ 0 N Aia-.,M Oil ~ ~a~ (;~ns, t;o[nmiHIon ~ Ancho,"~le I::' i I. e :-!: A t. a:~ I< a ARCO Alaska, Inc. %,,f'' Post Office BOx 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date: September 24, 1985 Reference: ARCO CH Finals. ~-o 3-26 ~-Temp Log 8-18-85 ~ -J~ 9-18 JDiff. Temp 8-9-85 '-' 9-18 /Spinner 9-11-85 --~~nner 8-1-85 ~ ~ 14-9B Temp Log 8-8-85 Run 1 5" GO 1 5" GO 1 5" Camco 1 5" GO 1 5" GO 1 5" GO Please sign as receipt of data. ~rau9 ~am AT0 1429C Trans 3~ Chevron ~ Phf l l tp$ D & M PB Well Files Expl. Services 'R & D Ext'. Exploration. Sohio' Marathon Texaco - Mobil ARCO Alaska. Inc is a Sut~s,cliary of Atlaf~hcRichtieldComDamy ARCO Alaska, Inc.~' Post Office 't:.. ~ 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 Date.: January 29, 1985 Re ference: ARCO Pressure Data 3-11 Pressure Survey '11-3-84 GO ~', ~Sta~ic'Gradi~n~ 1-11-85 Camco (c~,c~-~--e~ //-14-25 Pressure Fall Out 1-7-85 Camco 14-36 Pressure Fall Out 1-7-85 Camco /'C~ 14-26 Pressure Build-up 11-16/17-84 Camco n and return the attached copy as recipt of data. Received by Pam Lambert ATO 1429C · Alaska 0il ~, u~ uu,,,~. Anchorage Trans 014 Chevron 'Mobile D & M Mobile E & P Exploration Services Phillips Extension Exploration' Prudhoe Bay Well Files Texaco R & D Marathon .>-7~ ~'' ~ ~~~a=e of. AI~~ ~ ~' ' - i~iAY i'~ I~%~~ - . -Anchorag~ ARCO Alm_~-.ka, Inc. P.O. Box t00S60 Anchorage, ALas-ka 995i0 DATE' March ?q~ t°8=: m_: ,; .-' REFERENCE' ARCO C-osed HoLe F inal.~ Inject ion Pro','i Le/Yi::,ir.,ner CF'I_/TD'¥ MB w/1. i :.s"~: i ng I'n.iec. t i c,n F'rc, f i Le.,'"5:r.:, i'nner ,S'p inner 2.'p i 'nr~er I n j ec -!: i on F'r o I"' i t e/Z.:."p i ri'net ]"empera t ure/$p inner' a nd i-e't'urn -l.-he a't'i'ached c o i:: Y ..~ s r e c e i r--' +. of cta't'a, Received r.,,, HAVE A NICE DAY! I<eLLy McFarLa'dd ATO-.. 1 429F TRANS. ~:0=.'6_.. D I ~' T F;.'. I BUT I ON Mobil E & P [~!:i}:';h: i':l l':i-ps: ~ ~'""l~'"{':'U'ij i'i o e B a y W e l I. 'F' i l e '-: R & D ' :.:,,'e--~..'~'¢,.' ~ ~oh ,o - ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer February 5, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 3-4 DS 3-8 DS 3-11 DS 3-12 DS 3-13 DS 3-16 DS 3-17 Permit No. 76-51 Permit No. 76-73 Permit No. 03-11 Permit No. 76-58 Permit No. 79-71 Permit No. 79-93 Permit No. 79-102 Permit No. 7~7 ~1-0~77 Dear Mr. Chatterton: Attached are Completion Reports for work completed on the above-mentioned wells. Very truly yours, D. F. S cheve DFS/JB/mjb Attachments cc: Sohio Alaska Petroleum Co. File P1 (DS 3-4)W1-3 File PI(DS 3-8)Wl-3 File PI(DS 3-11)Wl-3 File Pi(DS 3-12)Wl-3 File PI(DS 3-13)Wl-3 File Pi(DS 3-16)Wl-3 File Pi(DS 3-17)Wl-3 File P1 (DS 11-7)W1-3 RECEIVED Alaska Oil & Gas Cons. Commission Ancl~ra~e ARCO Alalka, Inc. I1 · Sub.ldl·ry of AllantlcRIchfleldComp·ny ARCO Alaska, Inc Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer February 5, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 3-8 Permit No. 76-73 ~~m~ermit No. 71-177 Dear Mr. Chatterton: Attached are Subsequent Sundry Notices above-mentioned wells. Very truly yours, D. F. Scheve DFS/JB/mjb Attachments CC: Sohio Alaska Petroleum Co. File PI(DS 3-8)W4-3 File P1 (DS 11-7)W4-3 for work completed on the REC£1V£D t t lg 5 Alasl<a Oil & Gas ConS, c, omm[ssion Anchorage ARCO Al·aka, Inc. Is · Subsidiary of AllanllcRIchlleldComp·ny WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE dx Water Injector .. 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. ~1-177 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-20678 4. Location of well at surface 9. Unit or Lease Name 253'FNL & 81'FEL, Sec 33, TllN R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1514'FSL & 979'FEL, Sec.28, TllN, R15E, UM 11-7 At Total Depth 11. Field and Pool 1649'FSL & 1041'FEL, Sec. 28, TL1N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 62' RKB ADL 28235 12. Da. teSpudded1/31/82 13. Datem. D. Reached2 /16 /82 14'DateC°mp"Susp'orAband' 115' Water Depth' if offsh°re 116'No'°fC°mpleti°ns2/27/82 N/A feetMSL · ' 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9440'MD,8967'TVD 9380'MD, 8909'TVD YES ~ NO []I 2255' feet MD 1900' (approx) 22. Type Electric or Other Logs Run BHCS/DIL/SP/OR, FDC/CNL/GR/Cal, CBL/CCL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE'WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" ~1.5~ H-40 SUrf 80' 30" 275 sx Permafrost II 13-3/8" 72.0# MN-80 Surf 2659' 17-1/2" 2700 sx Fondu &'400 sx Permafrost C 9-5/8" 47.0# L-80& Surf 9429' 12-1/4" 788 sx Class "G" cmt. S00-95 24. Perforations open to PrOduction (MD+TVD of Top and Bottom and 25. 'TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 9,240 ' - 9,260 'MD 5-1/2" 8702 ' 8590' 9,270' - 9,306'MD *added on 1-13-85 '9,145' - 9,165'MD w/4 SPF 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. '9,184' - 9,192'MD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED '9,206' - 9,232'MD N/A TVD of Perfs: 8681 - 8775' 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) N/AI Flowing - Converted to injection on December 8, 19814. Date of Test Hours Tested PRODUCTION FOR el L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A RECEIVED Naska O~ & Sas Cons. Commission ,, Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE _ ;:.?'-'":"..'.' ; ':-' ::.-.... ;.: i.. ::',.ra~,¢~,.h.6,~'h:{.-s,.f-s'- .. NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. ..... Top Sadlerochit 8852' B398' N/A Gas/Oil Contact 9098' 8635 ' Base Sadlerochit 9326' 3856' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed _~/'~~J~ _ Title Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combuStion. · Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only:the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.), Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ALASKA ~LAND GAS CONSERVATION C · ~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL:~ OTHER [] Water Injector 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-177 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20687 4. LocationofWell 253'FNL & 81' FEL, Sec 33, TllN, R15E, UM (surf) 1514'FSL & 979'FEL Sec 28, TllN, R15E, UM (top prod) 1649' FSL & 1041'FEL, Sec 28, TllN, R15E, UM (TD) 5. Elevationinfeet(indicateKB, DF, etc.)62, RKB [ 6. LeaseDesignationandSerialNo.ADL 28325 12. 9. UnitorLeaseName Prudhoe Bay Unit 10. WellNumber DS 11-7 11. FieldandPool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) ~ Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and givepertinentdates, includingestimateddateofstartingany proposedwork, forAbandonmentsee20AAC25.105-170). Began perforating operation on 1-13-85. RU perforating unit and pressure tested equipment. RIH w/gun #1, shot interval 9212 - 9232' MD (4 SPF). Shut-in well, POOH, all shots fired. RIH w/gun #2, shot select-fire interval 9206 - 9212' MD (4 SPF), pulled up and shot select-fire interval 9184 - 9192' MD (4 SPF). Shut-in well, POOH, all shots fired. RIH w/ gun #3, shot interval 9145 - 9165' MD (4 SPF). Shut-in well, POOH, all shots fired. Secured well, RD. Ref: BHCS 2-15-82 RECEIVED FEB ! 1 1985 Alasl(a 0il & Gas Cons. Gommission Anchorage 14. I hereby certify that thgR~oregoing i~ true and correct to the best of my knowledge. Signed ........ Title Regional Engineer The space below for Commission use Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date __ Form 10~,03 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ~i~ ALASKA . AND GAS CONSERVATION C /IlSSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ Water Injector 7. Permit No. 2. Na-~Sp~ka' Inc. 81-177 3. Addcess 8. APl Number q~.O. BOX 100360, Anchorage, Alaska 99510 50- 029-20687 9. Unit or Lease Name Prudhoe Bay Unit OTHER [] 4. Loc~p~.ll & 81' FEL, Sec. 33, TllN, R15E, UM (Surf) 1514' FSL & 979' FEL, Sec. 28, TllN, R15E, UM (Top Prod.) 1649' FSL & 1041' FEL, Sec. 28, TllN, R15E, UM (TD) 5. Elevation in feet (indicate KB, DF etc.) 62' RKB ' 6. Lease Designation and Serial No. ADL 28325 10. Well Number D.S. 11-7 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed OPerations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. has converted DS 11-7 to water injection service..The well is part the Flow Station 2 waterflood project. The well began receiving water on 12-14-84. RECEIVED FEEt 1 .1985 Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby c,e, rtify that the foregoing is3,rue and correct to the best of my knowledge. Signed . ..... Title Regional Oper. Engineer The space below for Commission use Date Conditions of APproval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 STATE 5 SN DS2-3... Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer October 22, 1984 ,l Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: Permit No. 81-128 Permit No. 81-177 Attached are "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JB/mjb Attachments CC: Sohio Alaska Petroleum Company File Pi(DS 11-2)W1-3 File P1 (DS 11-7)W1-3 RECEIVED cc'r2 ~.las~a Oil & Gas Cons. Commission Ancllorage ARCO Alaska, Inc. Il - Subsidiary ol AtlantlcRichfleldCompany ALASt~ '.... STATE OF ALASKA ( ....... _,,_ AND GAS CONSERVATION MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~1 OTHER [] Water Injector 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-177 3. Address 8. APl Number P.O. BOX 100360, Anchorage, Alaska 99510 50- 029-20687 4. Location of Well 253' FNL, 81' FEL, Sec. 33, TllN, R15E, UM (surf) 1514' FSL, 979' FEL, Sec. 28, TllN, R15E, UM (Top Prod) 1649' FSL, 1041' FEL, Sec. 28, TllN,R15E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) 62' RKB I 6. Lease Designation and Serial No. ADL 28325 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 11-7 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. (Submit in Triplicate) Perforate [~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to add perforations on DS 11-7 with intent to convert to a water injection well. Perforations will be added to selected intervals within the Sadlerochit Sand from the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Intervals: 9145-9165' MD 9184-9192' MD 9206-9232' MD Ref: BHCS 2/15/82 w/4 SPF RECEIVED ~b~u~t Wort~ l~epor~l OCT 2 5 0i~ & Gas Cons. Commission 14. I hereby~tify that;~lregoi_ng is true and correct to the best of my knowledge. Signed ~'~'~ ~~ Title Regional Engineer The space below for Commission use Date Conditions of APproval, if any: Iil1' ~)IAIRY W. KIJG[£1t By Order of by Approved COMMISSIONER the Commission ^pproved Copy Returned Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. ' F'~C). Box '100360 Anchorage, ALaska 995~0 DATE:' Oct'ober 2, t:784 I:~:I.--_F'LEI;~iENCE · ARCO Ca:.sed Ho [e ~ D~,.., ~'' ., ~ 6 .... t 6 9 .... ~ ~..--84 CI..-,~/,":;p inner I),~', '!6 .... t . ':)-2-84 ~?pinner Log g., ~-,' , S- S t ' ,...,'.:-" - ,-.. '~- ,..,"*' --.- ,_, (:-'' 4 (.-;. I;.'. D £' t 'l - ,' 6- t '';'- 84 ., , '"' ..,. E p i i. ,:::, g / S I:) .a', .s.s' o v e r I..:.--~ y D ~ ~ 't 4- ti.'-, / 9- t" '-',-~ ,,., o-,:.-, ~ C: C L '1'",.'::, ;" :~ e t' '~ i n g '8 r i d g e D,.,9, 'i6-'t6/ 9 .... 'i2.---f34 Di'l"'f Temp I..og i::' L ti g C a m c c.', C a m c o DA DA GO [;-0 r e t' u r n !' h e - a '[' '~' a c h e d copy a:'-;' r~.'..'ce ip'~ ,.') 'f d a 'l' a, Receivecl By .............................................. I<eLLy Mc:Far Land ATO-i 429F AlasKa '¥RAN~, :If376 D I ~: T R I B U T .t: 0 N Chevron D & M ExpLora'J'ion Service.s Exten.~tion ExpI. orafion Ex xon Get'fy Mara 'thon Mob i l Hobi I. E & I::' F'hi l l ip.s !::' r u. ct h o e ii}].: a y W e l I F' i t. e s' F,,' & g ~'oh i o ARCO Alaska, Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 August 1, Reference: 1984 ARCO Cased Hole Finals D.S. 2-17~/ 5-23-84 D.S. 7-19--- 6-15-84 D.S. 9-14~ 7-20-84 D.S. 9-15/ 7-20-84 D.S. 9-16 7-21-84 D.S. 2 7-19-84 D.S. 11-7'-~- 6-15-84 D.S. 13-27 6-2-84 Basket Flowmeter Spinner Spinner Spinner Spinner Spinner Spinner CN/MSN/GR Diff Temp Run 1 Run 1 Run 1 Run 1 Run 1 Run 1 Run 1 Run 1 Run 1 5" Camco 5" Otis 5" Camco 5" Camco 5" Camco 5" Camco 5" Camco 5" DA 5" GO se sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429F Trans. #302 DISTRIBUTION Chevron D&M Drilling Exp. Services Ext. Exploration Exxon Getty Marathon Mob i 1 · ' Alaska Oil & 6'as Mobil E & P Anchorage Commission Phillips Prudhoe Bay Well Files R&D Carolyn Smith Sohio State of Alaska Past Othce Box 360 Anchorage. ~¢ ka 99510 Telephone ~ ~.77 5637 January 6, 1983 RE: ARCO Cased Hole Finals D.S. 13-21 D.S. 14-19 D.S. 15-14 D.S. 11-7 11-24-82 Temperature Survey 11-25-82 Spinner 11-26-82 Spinner 12-5-82 Spinner Run 1 y. Please sign and return the attached copy as receipt of' data. Camco Camco Camco Camco Becky Benedict AFA- 403 Transmittal #016 DISTRIBUTION NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO' MARATHON CHEVRON EXXON~ -..~ MOBIL D & M .~-, STATE OF ARCO Alasl<a. Inc. is a Subs~dlarv of AtlanticRichfieldComDan~ Anchorage. -ka 99510 Telephone 9t% '7 5637 January 3, 1983 RE' ARCO Pressure Surveys D.S. 16-14 D.S. 9-6 D.S. 9-1 D.S. 11-7 D.S. 17-9 .D.S. 4-6 12-16-82 Static Survey Camco 11-28-82 Pressure Build-up Survey Camco 11-17-82 pressure Build-up Survey Gearhart 12-05-82 Pressure Build-up Survey Camco ,. 11-19-82~ Static Survey Camco 11-19-82 Pressure Build-up-Survey Gearhart ease sign and return the attached copy as receipt of data. Becky Benedi ct AFA-403 Trans. #008 DISTRIBUTION NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON. EXXON MOBIL GETTY D&M STATE OF ALASKA DALLAS Alaska Oi! & (;as ARCO Post Olfice~J;~x 360 Anchorag~ ska 99510 Telephone ~ . ,,277 5637 December 16, 1982 RE: ARCO Pressure Surveys D.S. 3-8 11-20-82 D.S. 3-13 12-3-82 D.S. 3-15 11-21-82 D.S. 6-4 12-2-82 D.S. 6-11 11-11-82 D.S. 6-12 11-11-82 D]S. 11-6 11 - 7-82 D.S. 11-7 11-7-82 . D.S. 13-1 10-22-82 D.S. 13-3 10-23-82 D.S. 13-5 10-29/31-82 D.S, 13-22 11-22-82 D.So 13-23A 10-12-82 D.S. 13-24 11-19-82 Static Survey Pressure Build-up Static Survey Pressure Build-up Static Survey Static Survey Static Survey Static Survey Static Survey Static Survey Pressure Build-up Static Survey Static Survey Static Survey Camco Gearhart Camco Otis Camco Dresser Camco, Camco Camco Camco Camco Camco Camco Camco D.S. 17-5 11-18-82 Static Survey Camco "17-6 1'1-18-82 Static Survey Camco Please sign and return the attached copy as receipt of data. Becky Benedi ct AFA- 403 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON Trans. #662 EXXON MOBIL GETTY D&M STATE OF ALASKA DALLAS Ar~cho,' a§,,}, ARCO Alaska. Inc. is a Subsidiary o! AtlanticRichfieldC~m~ ~r~v ARCO Alaska, Inc.~'' Prudhoe Bay[.. ineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer December 13, 1982 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Re- D.S. 11-3 Permit No. 81-147 D.S. 11-6 Permit No. 11-6 D.S. 11-7 Permit No. ~ Enclosed are Completion Reports for work done on the above- mentioned wells. Very truly yours, D. F. $cheve Regional Engineer DFS/TKKW/1 mi Enclosures cc' Sohio Petroleum Co. RECEIVED DEC2 2 1982 Alaska Oil & Gas Cons, COmmission Anchorage ARCO Alaska, Inc. la. Subsidiary of AtlantlcRlchfleldCom pany ~ ' ~ S~ ' II ~'STATE OF ALASKA ~~ ALA ,'N, .~ AND GAS CONSERVATIO MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL~( GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-177 3. Address 8. APl Number P.O. Box 360, Anchorage, AK 99510 5o- 029-20687 4. Location of well at surface 9. Unit or Lease Name 253' FNL, 81' FEL, Sec. 33, T11N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1514' FSL, 979 FEL, Sec, 28, T11N, R15E, UM U.S. 11-7 At Total Depth 11. Field and Pool 1649' FSL, 1041' FEL, Sec. 28, T11N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Po01 62' RKB ADL 28325 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. [ 15. Water Depth, if offshore 116. No. of Completions 1/31/82 2/16/82 2/27/82] N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19, Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 9440'MD, 8967'TVD 9380'MD, 8909'T//I)'EsE~ NoEl] 2255' feetMD 1900' /aDDrOX~. · , 22. Type Electric or Other Logs Run BHCS/DIL/SP/GR, FDC/CNL/GR/~al, CBL/CCL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf. 80' 313,, ?7g~y P~m~¢~n~ f f 13-3/8 72 O# L-80 Surf. 2659' 17½" 2700~× FnnrllJ ~ 4flri_~x Permafrost C 9-5/8" 47.0# L-80 & Surf 9429' 12~" 7RF~× £1a¢~ ,l{'~ll rmf S00-95 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. 'TUBING RECORD r ,. interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 9240-9260' MD 8711-8775' TVD -~½" 8702' 8590' 9270-9306' MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATBRIAL USED : 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I · 11/15/82 Flowing I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 11/27/8; 13.2 TESTPERIOD I~ 2916 ?1147 fl 33 702 Flow Tubing. Casing Pressure CALCULATED I~ OIL-BBL' GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Pres's. 1'072 N/A 24-HOUR RATE '~ 5302 3721 0 27.ri 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A .RECEIVED ~laska 0il & Sas Cons. /~nChora~je Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 8852' 8398' N/A Gas/0il Contact 9098' 8635' ~ase Sadl erochit 9326' 8856' 31. LIST OF ATTACHMENTS 32. I hereby certify that the forego ,ng is true and correct to the'best of my knowledge ! Signed........ v- Title Regional Engineer Date I INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this'form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and iri item 24 show the producing intervals for only the interval rb~orted in item 27. Submit a'separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supPlemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 STATE OF ALASKA ALASKA L AND GAS CONSERVATION C v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL E~(x OTHER [] 2. Na f_Op.er_ator. 7. Permit No. ~O Alaska, Inc. 81-177 3. Address 8. APl Number P.0. Box 360, Anchorage, Alaska 99510 so- 029-20687 4. Location of Well 253' FNL, 81' FEL, Sec. 33, T11N, R15E, UN (surf) 1514' FSL, 979' FEL, Sec. 28, T11N, R15E, UM (top producing 1649' FSL, 1041' FEL, Sec. 28, T11N, R15E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) ' 6. Lease Designation and Serial No. RKB 62' ADL 28325 9. Unit or Lease N~me Prudhoe ay Unit 12. 10. Well Number D.S. 11-7 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations FX1X Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operations 11/5/82. Pressure tested tree, casing and wireline perforating equipment. Perforated 9240-9260' MD and 9270-9306' MD (ref: BHCS 2/15/82). with 4 shots per foot. Well flowed to tank during perforating, then to the I.P. separator. Ran static pressure survey 11/8/82. Ran and set SSSV and tested same. Installed and tested tree cap. Released well to Production Department 11/15/82. RECEIVED NOV 2 2' 1982 Alaska 0il & Gas Cons. Commis.~ion Anchorage 14. I hereby_certify that the foregoing is true and correct to the best of my knowledge. Signed ~w ~1~ ..... - - The space below for Commission use Engineer Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. ~ PrudhoeBay~, ,ineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer November 18, 1982 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton Re: D.S. 11-3 D.S. 11-6 D.S. 11-7 Permit No. 81-147 Permit No. 81-161 Permit No. 81-177 'Enclosed are "Subsequent" Sundry Notices deta,i'ling work done on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/TKKW/lmi Attachments cc: Sohio' Petroleum ARCO Alaska, Inc. Im a Subsidiary of AtlantlcRIchfleldCompany ARCO Alaska, Inc. Post Office B Anchorage, Alaska 99510 Telephone 907 277 5637 October 29, 1982 Mr. C. V. Chat C'hatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Re: Chatterton: D.S. ll-3 P'ermit No. D.S. ll-6 Permit No. D.S. q:l'~'7 Permit No. Attached are "Notice of Intention" on the above-mentioned wells. Very truly yours, D. F. Scheve Regional Engineer DFS-TKKW:mlc Attachments cc' Sohi.o Petroleum Co. 81-147 81-161 81-177 Sundry Notices work proposed ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA rLAND GAS CONSERVATION C ,.,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL i-~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 360 Anchorage, AK 99510 4. Location of Well 253' FNL, 81' FEL, Sec. 33, TllN, R15E, UM (surface) 1514' FSL, 979' FEL, Sec. 28, TllN, R15E, UM (top producing 1649' FSL, 1041' FEL, Sec. 28, TllN, R15E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RKB 62' I ADL 28325 7. Permit No. 81-177 8. APl Number 5o-029-20687 9. Unit or Lease Name Prudho~ Bav Unit 10. Well Number D.S. 11-7 11. Fie,u and Pool Prudhoe Bay Field Prudhoe Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon '[] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perforate selected intervals'within' the Sadlerochit Sand for production from the Prudhoe Bay Unit. .Upon perforating, the.well will be flowed to a tank for initial clean-up then production will be to the flow station. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to working pressure, The SSSV will be installed at the conclusi~on of the perforating and clean-up operation. The proposed perforated intervals are as follows: 9240'-9260' MD 9270'-9306' MD Ref:. BHCS 2-15-82 Subseq¥c ~ ".'.::,::;.: lle4~,orted on Form No. ,~ Dated/_/__1~~ 14. I hereby2,~rtify that the f~egoing is true and correct to the best of my knowledge. The space below for Commission use Date Conditions of Approval, if any: Approved by Form 10-403 [ ~pproved Copy ,~ Returned ? _ By Order of COMMISSIONER the Commission Date ....... Submit Intennons in Triplicate Rev. 7-1-80 and "Subsequent Reports" in Duplicate Ancnoraae. Al~,s~a 99'510 .,' .,' Tele~hor~e ~0~ 7 5637 May 10, 1982 Reference: ARCO MAGNETIC TAPES & LISTS D.S.14-28/ 3/19/82 2/26/82 D.S,13-17'~/13/82 D.S.14-9B~-..~ 4/10/82 D.S.15-14/~ 12/25/82 DS..14-gB1/ 4/21/82 ~ape # ECC 1252 Tape # ECC 1238 Tape # ECC 1243 Tape # ECC 1275 Tape # ECC 1192 Tape # ECC 1283 Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal # 148 DISTRIBUTION NORTH GEOLOGY. R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON D&M ~'~'~,~ Oil & Gas Cons, C, , ,' GEOLOGY ARchorago STATE OF ALASKA ARCO Alaska, Inc. April 30, 1982 Mr...C.V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commission ~001Rorcupine Drive Anchorage, Alaska 99501 Subject: State Reports Dear Mr. Chatterton: Enclosed are Well Completion Reports for the following drill sites: 11-6 14-29 15-2 1A-15 (ReVised) Also enclosed are monthly reports for March on these drill sites: 2-19 15-4 2-20 Eileen #1 13-17 West Sak 24 13-23A 1A-16A (Sidetrack) 14-9B IE-9 14-28 Oliktok Pt. #1 14-30 West Sak 25 15-3 We are also including plug and abandonment subsequent sundry reports on Eileen #1 and 1A-16. The reports on Eileen #1, Oliktok PL. #1, and the two West Sak Wells are of a confidential nature. We would appreciate it if you could store information concerning these wells in a secure area. Sincerely, P. A. VanDusen District Brilling Engineer PAV/JG:pb eno. GRU4/B4 APR 0 i982 .., "i ~' ' STATEOFALASKA WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-177 3. Address 8. APl Number P. O. Box 360, Anchorage, AK 99510 5o-029-20687 4. Location of well at surface i -- 9. Unit or Lease Name 253' FNL, 81' FEL, Sec 33, T11N, R15E, UM1 LOCJkTIONSI · Prudhoe Bay Unit VERIFIED1 At Top Producing Interval ~.~ it 10. Well Number 1514' FSL, 979' FEL, Sec. 28, T11N, R15E, UM ~ls,~ 11-7 At Total Depth JI~HL J[~ _:.! 11. Field and Pool 1649' FSL, 1041' FEL, Sec. 28, T11N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i ] Pool 62' RKBI ADL 28325 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 01-31-82 02-16-82 02-27-82J N/A feet MSL 1 17. Total Depth (MD+TVD)18.Plug Back Depth (MD+TVD)19. Directional Survey J 20. Depth where SSSV set J 21. Thickness of Permafrost 9440'MD, 8967'TVD 9380'MD, 8909'TVD YES~] 'NOF--) 2255t ' feetMg 1900' (approximate) 22. Type Electric or Other Logs Run BHCS/DIL/SP/GR, FDC/CNL/GR/Cal, CBL/CCL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40'" Surf 80' 30" 2758x Permafrost II 13-3/8" 72.0# L-80 Surf 2659' 17-1/2" 2700SA Fondu & 400SA Permafrost C 9'5/8" 47.0# 'L-80" Surf 9429' 12-1/4" 7888x Class G cmt S00-95 24. Perforations open to Production (MD+TVD of Top and Bottom and . 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) N/A ~ 5-1/2" 8702' 8590' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A ;, . , · , 27. PRODUCTION TEST ' Method ~of Date;First Product.on. , Ope~at. ion (Flowing, gas lift, etc..) ,. N/A N/A. ~ "~" Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE JGAS-OILRATIO TEST PERIOD ~ I Flow Tubing . Casing.Pressur, e . ,CALCULATED OIL-BBL G/~S-MCF WATER-BBL. OIL GRAVITY-APl (cor'r) Press. 24-HOUR RATE ~' i,,. . . ' .... 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A ..... ~ ,, · :.. .~ ;. . .. : ' RECEIVED · . , APR 3 o 1982 " : ":' ~ ~ · ' "" ~.!~skB 0il & Gao Cons. C0mmJss]0~ Form 10-407 '~ Rev. 7-1-80 GRU3/Al8/19/20 CONTINUED ON REVERSE SIDE Submit in duplicate NAME .... Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top'" Sadleroch'it 8852''i' ' ' 839'8' N/A. G/0 Contact 9098' 8635' Base Sadlerochit 9326' 8856' , 31. LIST OF ATTACHMENTS Drilling History, Gyro'Multishot Survey (2 copies) 32. I hereby certify that the foregoing is' true and correct to the best of my knowledge Signed_ ~ ,,, ~ ,,,Title Area Dr]g. Engr. D~te~ ~//~/'//~> [2 .......... INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection,~ air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: I'f this well is completed for separate production from more.than one interval (multiple completion), so sta~e in item 16, and in item 24 show the producing intervals f~'only the interva~ reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none" · Form 10-407 DS 11-7 Drilling History NU 20" Hydril and diverter. Spudded well ~ 0400 hfs, 01/31/82. Drld 17-1/2" hole to 2675'. Ran 64 its 13-3/8", 72#/ft, L-80, BTC csg, w/shoe ~ 2659'. Cmtd 13-3/8" csg w/2700 sx Fondu cmt & 400 sx Rermafrost C. ND 20" Hydril and diverter. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BORE & tstd to 5000 psi - ok Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg tO 1500 psi - ok. Drld FS & 10' new form. Tstd form to 11.5 ppg EMW - ok. Set 155 sx Class G cmt balance plug on to~p ~~,(200' plug). Drld 12-1/4" hole to 9410'. Run BHCS/DIL/SR/GR, FDC/CNL/GR/Cal. Drld 12-1/4" hole to 9440'. Ran 183 its 9-5/8", 47#/ft, L-80, BTC csg & 48 its 9-5/8", 47#/ft, S00-95, BTC csg w/shoe ~ 9429'. Cmtd 9-5/8" csg W/788 sx Class G cmt. Instld 9-5/8" paekoff & tstd to 5000 psi - ok. Tstd csg to 2000 psi - ok. Cire hole clean ~ 9380' PBTD. Ran CBL/CCL/GR. Arctic packed 9-5/8" x 13-3/8". Displaced well to NaC1. Ran 5-1/2" completion assy w/tail { 8702'& pkr ~ 8590'. Tstd tbg hanger & paekoff to 5000 psi - ok. ND BORE. NU tree & tstd'to 5000 psi - ok. DisplaCed well to diesel. Dropped ball & set pkr. Tstd tbg to 3000 psi & annl to 200 psi - ok. Tstd tbg to 200 psi & anni to 3500 psi - ok. Closed SSSV ~ 2255' MD. Instid tree cap & tstd to 5000 psi - ok. Secured weII& reIeased rig ~ 2200 hfs, 02/20/82. ' Gyroscopic survey ran 02/27/82. Note: The fish consisted of the bit and bottom end of the dyna drill. OG:hrl o4/13/82 GRU3/A21 APR o I 82 Oil & Gas Cons. i Eastman A PETROLANE COMPANY REPORT of SUB-SURFACE D IREC TI ONA L SURVEY ARCO ALASKA ~INC. COMPANY DS 1!~ Well Number: 7 WELL NAME Prudhoe Bay, ~orth Slope, Alaska LOCATION JOB NUMBER TYPE OF SURVEY A0382G0407 SURVEY BY D Pefferkorn APR 0 6 OFFICE AZaska DATE 27-Feb-82 Eastman Whipstock ~. o. Box 4-,9?O/Anchorage, Alaska 99~09/(90~) $49-4517 A PETROLANE COM~ March 22, 1982 ARCO ALASKA, INC. P.O. Box 360 Anchorage, Alaska 99510 Well Number: 11-7 Location: Prudhoe Bay, North Slope, Alaska Type of Survey: Gyro Multi Shot Date: 27-Feb-82 Method of Computation: Radius of Curvature Surveyor: D Pefferkorn Job Number: A0382G0407 Attn: Bob Hines Dear Mr. Hines, We are enclosing the original and sixteen copies of the Gyro Multi Shot Survey run on the above mentioned well. To date, the following distribution has been accomplished: A;' '1 copy telecopied to E/W North Slope office for delivery to ARCO fieid representives. B~ ''16 copies delivered to drilling for in-house distribution. C~'3 copies for E/W permanent well files. We wish to take this opportunity to thank'you for calling on our services and trust that we may continue to serve your needs in the future. Sincerely, District Operations Manager ST/bb cc: file enclosure Directional Drillers/Sub-Sudace Surveyors/Instrument & Tool Rentals/Sales/Worldwide ARCO AI_AS~A,. ~NCo. DS'"'II~ WELL"NO;'~7-~'~GMS ......... F'RUDHOE BAY, NORTH SLOPE, GMS, 0-~300 MD, SURVEYOR; PEFFERKORN CAMERA NO! ~7~ GYRO NO: 620 ~4 DEG. A/U NO: 258 FORESIGHT;~ S14W DATE RUN:27-FEB-82 VERTICAl_ SECTION CALCLII.ATED IN F'I_ANE OF RECORD OF SURVEY RADIUS OF CURVATURE METHOD DS 11, WELL NO: 7 GMS dOB NO; .:'RUDHOEBAY, NORTH-SCOPE, Ai:ASKA AO382G0407 T I ME DATE . . TRUE MEASURED'DRIFT ......... DRIF1- .........COURSE VERTICAl: VERTICAL"SUBSEA .... ............ C'qZ"O'~SU R E DOGLEG DEPTH ANGLE DIRECT]ON LENGTH DEPTH SECTION TVD C 0 0 R D ! N A T E S D~STA~CE DIRECTION SEVERITY FEET D M D FEET FEET FEET FEET FEET FEET D ~ DG/].00FT 500. 600. ~ .~ . 900. O. 0 0 0 O. 0.00 100. 0 0 0 100. 100,00 200. 0 15' S"-31 ....W ......... 1'00. ' 200",00 300, 0 J5 S 33 W 100, 300.00 400, 0 0 0 ]00. 400.00 0 15 S 25 100, 500.00 0 15 S 2~ 100. 600.00 0 SO S'-'26 100. 699.99 0 0 0 100. 799.99 0 1,5 S 28 100. 899.99 1000o 1100, 1200. 1300. 1400. 1500, 1600, 1800. 1900. 0 15 S iS W ]00. 999.99 0 ~0 $ 34 E 100. ]099.99 0 0 0 100. 1199.99 0 15 S 81 W ]00. ]299.99 0 50 S 58 W 100, ]~99.99 0 15 S 80 W 100. 1499.98 0 SO S 80 W ]00. 1599.98 0 SO~' N 86 W ..... 100.' ]699~98 0 30 S 79 W 100. 1799.97 0 30 S 42 W 100. 1899.97 0.00 -62,00 0,00 0,00 0,00 0 0,00 38.00 0,00 0,00 0,00 0 -0~'10 ']-38'~"00 .................. 0~9--$ ................... 0;'~1 ........ W ..........0~"22 ..... S 31 -O.SO 238.00 0.56 S 0o~4 W 0.65 S S~ -0.~9 338.00 0,74 S 0,46 W 0.87 S 32 -0,51 -0,87 -1.52 -~,96 -2,07 438.00 0,94 S 0.55 W 1.09 538,00 1,36 S 0,56 W 1.47 637~-99 .......... t'~96--S ........... O'~-~-W ................... 1-~98 737,99 2,35 S 0,]0 W 2,35 837.99 2,54 S 0,20 W 2.55 -2,34 -2,93 -3,37 -3,29- -3,17 937,99 2,95 S 0,;35 W 2,97 S 1:0~7:~-99".:"' 3 · 57 S 0 · 24 W 3 · 58 S 1':l. < Y:.:99 , ?:~9 0 J E 3'~'94 S S .'97~ 21 W 3.97 S : ~, , ~:,~ ~,~:. , .:,.? ~:~- :: :. ~:S;~?~:::<~:{?~ -2~81 J5~7.98 ~,55 S 2,0Y W 4~99 -2*40 163'7~98 ..... 4-~-59--S ....................... 2":94-W ................... 5~45 -].99 ]737,97 4,64 S 3,8] W 6,01 -1.97 ]837.97 5.07 S 4.55 W 6,81 0 0,00 0 0.00 0 W 0;25 40 W 0,0] 0 W 0,25 S ~0 36 W 0.25 ~ ~.~ W 0.20 $ 8 24'W ...... 0';"25 S 2 22 W 0.50 S 4 29 W 0.25 6 48 W 0.07 ~ 46 W 0,38 0 7 E "0;50 2 58 W 0,25 11 0 W 0.29 S 17 49 W 0,28 S 24 29 W 0,25 S 32'~"38' W 0'~i2 S ~9 21W 0.1~ S 41 57 W 0oS2 ~000. 0 ]5 S 27 W 100, ]999.97 -2,24 1937.97 5,60 S 4,92 W 7.46 S 41 18 W 0.27 ~. ~.00, 0 15 N 80 E ]00, 2099,97 -2,59 2037,97 5,89 S 4,72 W 7,54 S 38 41 W 0.45 .~,.]s_200~ I 45 N 55 E 100. 2199,'95 ' -2~85' 21S7',95 ................ 5~2S-S ........................ 3~'t2"'"'W ................. 6'~08 S 30'48~W ......... t'~"53 ...... 2300. 1 45 N 59 E 100, 2299.90 -2,76 22~7,90 3,56 S 0,55 W 3,61 S 8 51 W 0,12 2400, 2 0 N 57 E 100, 2399,85- -2,71 2337,85 1,83 S 2,22 E 2,88 S 50 34 E 0,26 2500, 2 0 N 71E 2600, I 45 S 82 E 2700, 1 45~ -S 70 E 2800, i 45 S 64 E 2900, ,1 45 S 54 E 100, 2499,79 -3,03 2437,79 0,30 S 5,35 E 5,36 S 86 47 E 0,49 100. 2599.73 -4.44 2537.73 0,01N 8,58 5 8.58 N 89 56 E 0.91 ]00. '2699~69 6,61 2637.69 O.?3~"S ............... t'~1",54-"E ..........1't.56" S 86'23'E 0.37 ...... ]00, 2799.64 -9,09 2737,64 1,9P S 14,35 E 14o48 S 82 23 E 0,18 100. 2899,59 -1~.78 28~7,59 3,49 S 16,96 E 17,~2 S 78 22 E 0.~0 TRUE 4EASURED-'DR'IF'~ .......... DR[-F'T .......... COURSE---VERTICAI; VERTICAI,-SUBSEA R-E--'C---T-'.~A.~N----G-.~.Lit':"A~'-R ........ C-[:--O $.U R E DOGLEG DEF'TH ANGLE DIRECTION LENGTH DEF'TH SECTION TVD C O 0 R D I N A T E S DIS'lANCE X)IRECTION SEVERITY FEET D H D FEET FEET FEET FEET FEET FEET [~ H DG/100FT 3000. I 45 S 32 E 100, 2999.55 -14.76 2?37.55 5,71 S !9,03 E 19,87 S 73 18 E 0,67 3100. 0 30 S 34 E 100, 3099.53 -J6072 30~7,53 7,36 S 20,~0 E 21,41 S 69 54 E 1.25 3200, "0"30 ...... S"~20"-W ............. t-OOi ......~'1-9'?~52" -17,48 3~37~.~ 8,19 S ~0.,0 E ~.1,80 S'~-67 56"E 0',45 3300, 0 15 S 26 W 100, 3299,52 -17,87 3237,52 8,80 S 19,95 E 21.80 S 66 12 E 0,25 3400. 0 15 S 20 E 100. 3399,52 -J8,22 3337,52 9,22 S 19,92 E 21,95 S 65 10 E 0.20 · 3500, 0 0 0 100, 3499.52 -J8.43 3437,52 9,42 $ 20,00 E 22.11 S 64 46 E 0.25 3600, 0 15 S JO W 100, 3599,52 -18.59 3537,52 9,64 S 19.96 E 22.17 S 64 14 E 0.25 37"'. 2 30 N'~58~W 100",'' 3699,-48 -t8034 3637,48 .... 1-.0~---47--S ................... J'-8~--t-O-~E ..................... 20~'9J S~ 59'58-E 2~.60 38~', 5 45 N 48 W 100. ~799.21 -11.67 ~737,21 6.14 S 12,37 E J3.81 S 63 35 E 3.32 100, 3898.S1 3900, 9 30 N 39 W 4000, 12 15 N 34 W 4100. 14 15 N 39 W 4200,- J4 30 N 39--W 4300. 14 45 N 37 W 4400, 15 0 N 37 W 4500, 15 30 N 37 W 100, 3996.50 100, 4093.84 100, 41.90.71 100, 4287.47 100, ' 4384,11 . . 100. 4480.59 1,29 38~6.31 3.47 N ~.24 E 4.75 N 43 3 E 3°92 20.06 3934.50 18.63 N 7,97 W 42,88 4031~84 37.05 N 21,60 W 67.48 4128~71 ~o~,.~--~_~-.~,~ ',~. ~. ?2.55 4225,47 '7'g~24~N ....... ~'i ~ 77 W 144.27 441 8,~o9.'~' ~..1;19,'7~?..N 84,05 W 20.27 N 2~ 10 W 2.90 42.89 N 30 15 W 2,30 67,53 ........ N-~--29 W .... 0.25 ....... 92,72 N 34 41W 0.56 118,38 N 35 ~ W 0,25 144.67 N 35 31 W 0.50 4600, 15 45 N 37 W 100. 4576,90 ~71.06 4514.90 139,26 N 1.00,26 W 17~.59 N 35 45 W 0.25 ' 4700. 16' O' N'36 W' - 100.' 4673.'08' 198.30 461'1,08 ...... :]6'~'.25--N :"-'tt6-~5~'-W .......... ~98',"95 N'-35"5t W .... 0,~7 .......... 4800, 16 0 N 35 W 100, 4769.21 225,79 4707,21 183,69 N 1~2.54 W 226,51 N 35 49 W 0,28 4900, 16 15 N 34 W 100, 4865.28 25~,52 4803.28 206.57 N 148,27 W 254,28 N 35 40 W 0,37 ~000, 17 30 N 33 W 100, 4960.97 282,5~ 4898,97 230,78 N 164,29 W 283,28 N ~5 27 W 1.28 ~'~2~00' 20 15 N ~ W ~00. 5055,58 ~4.87 4993°58 258,21N ~81,4~ W ~15,58 N 35 6 W 2,82 00. 24 O' N'28 W ..... ]00. ..... 5148.20' "352.50 5086~'20 ...... 290,'98'-'N ......... t9~',97'~W ...........353',0'? .... N-"'34"~0' W ............ 3'.'~2 ....... 5300. 26 45 N 27 W ~00o 5238.54 375.26 5176.54 ~28.99 N 2!9.76 W 5400. 29 0 N 27 W ~00. 5326.94 441.88 5264.94 ~70.64 N '240.98 W 442.10 N 33 2 W 2.25 .................................................................................................................. 5500, 29 45 N 26 W 5600, 29 45 N 25 W 5700~ "30' 'O N' 24"W ' 5800. 30 15 N 23 W 5900. 3~ 0 N 22 W 100, 5414,08 490,77 5352,08 414.54 N 262,87 W 490.86 N ~2 23 W 0.90 100. .ow090 540,14 5438,90 4.,9.33 N 284.2~ W 540.16 N 3~ 45 W 0 50 100'." 5587-,61' 589.60 ' ~.~.,o6] ~04'-~66-'N .............. 304-~89-'W ......... 589-~'60 ..... N""~i 8 W 0.56 ~00, 56740~0 639,33 5612,~0 550,68 N S24,~0 W 6~?.38 N 30 32 W 0,56 100, 5760.~5 689.68 5698.15 597.74 N 344,~? W 689,86 N 2? 57 W IS 11, WELL NOI 7' GMS, JOB NO ~RUDHOE-BA'Y-~ ..... NORTH-"'SLOF'E-'- - AIiASKA AO382G0407 T I ME [lATE TRUE tE~SURED'-'DR'IFT ........... DRIFT ............ COURSE'-VERTICAL DEPTH ANGLE DIRECTION LENGTH DEPTH FEET D M D FEET FEET 6000, 31 0 N 21W 100. 5845,87 6100· 31 0 N 21 W 100· 5931·59 6200, 3I-'45-'-N .... Ig--W ........... I00, -601'6·'V7 6~00, 31 45 N 21W' JO0· 6102·00 6400· 32 0 N 20 W 100· 6186,~2 . . 6500, ~2 0 N 20 6600· ~2 0 N 20 -- 67~q~ .... 31' 45 N'?20 6~,..~-0 31 45 N 21 6~00· 31 0 N 21 DOGLEG SECTION TVD C 0 0 R D I N A T E S D:(S'IANCE DIRECTION SEVERITY FEET FEET FEET FEET D ~M DG/IOOFT 740 44 ~78~·87 645,66 N ~63·27 W 740,84 N 29 ~' W 0.52 79],12 5869.59 693,75 N 38].73 W 791o83 N 28 49 W 0·00 842',18 ..... 5954",97 ..... 742'~'67~'N ~99'~"5'~'-'W ........ 843~"32 ....... N'28~17'W1,28 8~7,7~ 6040,00 7~2,11N 417·5~ W 8~5,42 N 27 48 W 1,05 ~45·~7 6124,~2 841,58 N 4~o02 W ~47o82 N 27 23 W 0,58 ............................................................................................................. W JO0, 6271,7~ ~7,&4 &20~,73 8~1,37 N 454,15 W 1000,40 N 27 0 W 0~00 W 100, ~5~,.,~ 104~,62 ~2~4,5~ ~41,17 N 472,27 W 105~ 01 N 26 3~ W 0 O0 W- "JO0,- 6441,45' J. J01'·4'! 6~7~,'45 ..... ~O-~"7~'~'N ......... 4~O'~'~-W ......... 1~'~05'-~-48 ..... W JO0, 652&·4~ 1153,10 &464·4~ J040,08 N 508,76 W ~157,84 N 26 4 W W 100· 6611·86 1204,34 654~,86 1088,68 N 527,42 W J20~,71 N 25 5J W 0,75 W 100o &6~7,58 J255·02 6635,.8 113&,77 N 545,87 W 1261,04 N ~ ,20 W ~00, 6784·~8 1~04,5~ 6722.,'18 1182,42 N .6& W 1310o~ N ~.~ o 1~,~,,~81~.N ....... ~.~8~, 14 W 1358;23~-' N'"25'42-W W 100, 6872 26 1351,88 68J0,26 ~ W 100. &~&1·17 ~3~7,&7 &8~,17 1..6~oO&~N ~:!J.~. W 1403,8~ N 25 5~ W 0,50 ~'6~.,1~ W 1448,53 N 26 0 W 1,17 W 100, '7050,56 J442,-47 8988,56 :..~01'~'86~,:N~' 1486.48 7078:0/~4x"-.I~400'19;?N 656,81W 1492.48 N 26 7 W O·5J J530.11 7168.32 J~770~8 N 67806~ W 15~6.03 N 26 13 W 0,25 1572.95 '7258-,67 141-5sOg-'N 700~0'6"-'W ...... ~'578'-~'7~ .... 16J4,61 7349..,8 1451,18 N 720,89 W 1620,~7 N 26 25 W 0.75 J655,48 7440·84 1486,40 N 741,64 W 1661,J5 N 26 31W 0,48 W 100, 75~4 55 1695 34 7532 55 1"~ · . . .,~0,93 N 76J057 W 1700,95 N 26 ~6 W 1,28 W 100. 7686,85 1733,78 7624.8~ 1~40~7 N 780,.~ W 17~.38 N 3~ W 0.75 W-' 100, ..... 7779,57 --1771-,22 .... 771~7'i57 ........... 1'587",-18'N ............. 798'~-6'~'"W ....... 1776-~'80 W JO00 7872,~2 1807,05 7810,~2 1618,21N 816,59 W 1812,57 N 26 47 W 1,50 W 1000 7966,89 J841,24 7904.8~ 16470~8 N 8~3043 W 1846,74 N 26 50 W 0·61 100· 8061,51 1873·56 7999,5J. 1676,27 N 84~.11 W 187~,06 N 26 52 W 1·75 100, 8J56,62 1904,45 8094,62 1703,17 N 864,~ W 1909.93 N 26 54 W 1000 8252',12 1934,08 .... 8190,'~2 1729,10"N ......... 878~"70~W ...... 1~.·.6 'N-~26 56-W 1,61 - · JO00 8348·12 1961,98 8286,12 1754,0~ N 891·41W 1967·55 N 26 56 W 0,75 100, 8444,3J 1989.20 8382031 1778,72 N ~0~,18 W 1~94 89 N 26 7000. ~1 0 N 21 7100, 29 0 N 27 7200, 27 30 N 31 7~00. 27 0 N ~1 7400. 26 15 N 2~ 7500. 26 0 N ~0 W 100, 7140·~4 7600, 25 45 N ~0 W 100. 72~0.32 ~' 7700, 25' 0' N ~0 W' 100',' 7~20,67 7800. 24 J5 N ~0 W 100, 7411,58 ~ ~ 84 7900, 24 0 N ~1W ]00, 7.,0~, ~000, 2~ 0 N 29 ~__..00 22 15 N 29 -"u' oo 8300, '20 ~5 N ~0 8400° 1~ 45 N 2~ ............. 8500, 18 0 N 2~ W 8600, 18 0 N 30 W ..... 8700. 16 30 N" 28-W -. 8800, 16 0 N 26 W 8~000 15 45 N 25 W 11, WELL NO; 7 GMS' JOB NO; AO382G0407 TIME [;ATE ................................. *~ '~ ~.-MAR-8~ ?RIlBHOE--BAY,'NORTH'SLOPE-~ ...... ALASEA i ...... - 130~8019 ~ ' TRUE ~EASURE~I DRIFT DRIFT COURSE--.VERTI-CAIz-VERTICAt, SUBSEA R E-.-.C--T----A---N--G-..U---lz-A-R DEPTH FEET ~000, 9100~ ..... 9200° C L 0 S U R E DOGLEG ANGLE DIRECTION LENGTH DEF'TH SECTION TVD C 0 0 R D I N A T E S r;](S'I'ANCE DIRECTION SEVERITY D H D FEET FEET FEET FEET FEET FEE'T D M DG/iOOFT 15 0 N 25 W ~00, 8540,7S 2015,55 8478,7~ 1802,75 N ~14,39 W 2021~39 N 26 54 W 0,75 14 30 N 25 W 100, 8637,4~ 2040,86 o.~.,43 1825,8~ N 925,15 W 2046,84 N 26 52 W 0,50 14 30 .....N-'25"'W ......... 100~ ...... 8734-~-25 ..... 20'85'*'75 '°z'~°o~-~. 0 o~'-l-B48','52-N~.. . 935,?~"'W 2071~ ~ 14 0 N 25 W 100, 883J017 20~0,22 87&9,17 1870,83 N 94&,J3 W 20~6,4& N 26 50 W 0,50 ~ROJECTED TO TD ~440, 14 0 N 25 W 140, 8~6700J 2123,8~ 8~05,01 ~01,52 N 960,45 W 2130,~2 . FINAl. CLOSLIRE - D~RECTION; N 26 DEGS 47 MINS 5~ SECS W - DISTANCE; 2130~-32'"'-FEET N 26 48 W 0,00 ARCO ALASEA, ........... BS'"-"I"I-~ ..... WELL"-' NO; 7~" GMS JOB'""NO'~ ...... AO3'82G~O~-07 PRUDHOE BAT, NORTH SLOPE, Al_ASEA GMS, 0-9~00 MD, SURVEYOR; F'EFFERKORN DATE RUN;27-FEB-82 CAMERA NO; 317~ GYRO NOI 628 34 DEG, A/II NO; 258 ..... FORESIGHTI S~4W WELL NO; 7 GMS- :'RUIIHOE--BAY, NORTH SDOPE,~-ALASKA -MARKER-. ....... CODE ............. NAHE TOP OF SAD G/O CONTACT -BASE-OF.--SAD- PBTD TD .lOB NO; AO582G0407 TIME [;ATE TRUE S[IBS~A MEASURED VERT~CAE--HD-TVD-VER~T~-I-CAE-'R--E-C-~T"'A'-N~"G"'U' L~A R C L'"'-'-O" S~'-'[t"~'R-"'E ............... VERTICAL DEPTH DEPTH [~IFF [;~F'TH C 0 0 R D I N A T g S DISTANCE BIRECTION THICKNESS FEET FEET FEET FEET FEET FEET D M 8852.00 8598.]4 453.9 8536.14 ]766.87 N 897.5J W 198].77 N 26 56 W 90~8,00 86~5,50 462,5 8573,50 ]825,56 N ~24,9J W 2046,5~ N 26 52 W ~526, O0 ...... 885~-~4~469-~"6 ..... 8'7'94-,40 .......]87&~ 5'5~-N ........ ~48 ~'7~ W 2102¥'75 .......... ~80,00 8~08,7~ 471,2 8846,7~ 1888,~7 N ~54,~ W 2115,81 N 26 4~ W ~440,00 8~67,01 47J,0 8~05,01 1~01,52 N ~60,45 W 2150,52 N 26 48 W ,%,.:..- ........ . . .. . · o.;_ o.-..,- ..... ;..:-, .... ~: · ._. _-.,:,~.:~;- - ._ :: - .~... .... · ~,~ . . .-.%...'_~r:%-"-;..'..:- '-'-. :.-'-o:.:;-',:.-'.' 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SU z:SURFA CE.-..- .... -- - . ....... . · . . .. .... . ............. - .... i:u:-~" " .L': :f'.'.' ' '" ' ' ':" "'": .... ~ "-':':'*: ':" .. * ....... .- .. . ............. "*'. "' ',*.'L ..... '.' ....... .*. ..... .:. ........ .... .. ... · --. o-. - · -,_ ..... ..,- ._-_ .,. *-. :. ,-.~. ~ , . ................ :::' :; :"': ', '" i:-:: ;-i. _!ii:ii!Z:"SUR. VE Y ..,... , ., .... . .: :..i ':'-' i i : ... · . ... '-- .t ............ ."'"":-. ' :::':':'"'~::::-u' ;"' :' ':. :!~i,:/'il .,...:-: '; ~':f' ;': ". : "'.' ;'-: ': ~ :!'.--..:;i:' i' : :: '.'..:- '-:',--.-~..-:, -- '-":- · - · . ..... . ..- _.. · _. .. ..... -- .~. . ... . . . .... .. '..'.. . - : :....-. .... -. . · ....... -~~ · . . ' ": .:' Z' . ,. '.:,' ,: ...... : . ' ,- u-:: ' - · .. . ....... · ... " ...... . ...... · "::z::" · . - - .- - · .;...-- .. - .... .. :: . . · .....:**..* .:. -. .. :" .... ' '.Z ,"':':'::'""::':'-.,,...*-,. ',v ':: ::'.'; ":}~'.": '" .... ':"::'::'-" : ~'- ' ' . ';- . .' . .-. '.- ARCO AI.ASK-Ar INC. - --- . ~ COMPANY . : . . _i. : ....... . . · . ... ..- - __- ..... ..~ ,:.--........ :. . . .-...::..... .. .... .:::.:......... ................ DS 11~ ~e'l_l l'-lumbor: 7 .. .'~i:i ii'. : ,'~::' - · W~Lk NAMI= .- .- ........... - ..... .... ... ... Prudhoe Bay, North, Slooe, Alaska .... .. LOCATI ON ........ . · :' ' ' 'Z. :: ' - -" . ' - . . .; . - .:..'~: .. ..:.....' ....... · .......... .. - ......... -. · ' .ZT',..:-'.- -;.-.-:.-;k-:;-'. :'., .. .......:-.: ...... .:..;'.:'*-~.k-.:'~...:. :.. ' :*-.: : - ........ :': .... :' :. *' "":'.' ' ".:: /'7 :i'; .:'- :*"*.:::'!: ~i..:'.-.*.'~}' ' _':.'.:" --" :"*'-':'- ·, .-.-.. - . .... · [ *_ .;.-..::: ...... '"/'"JOB NUMBER ...... ... TYPE OF SURVEY ,.....- '. .... :*..- DATE - .- ..,. .. .* - :-'.***',{... -: ;7;-!:' "..7 - - · - ._ -... . ................ --A0182D0244 - ""'*- -..-, -*.' Directional Single Shot ' '16-Feb-82 - "..'".' '::" .'. *: .... ._:: . .....k:v*' ~... 'RECEIVED .... .MAR 1 9 ~.,q82 "' ~lasKa 0il &'Bas CO~s. -... , A~che'rage ":':'.. -"- - .... - - - OFFICE- -'' /' ...... "'- ' .:::'L '. ............. ' ' . . --. - ' ' Alaska "' February 17, 1982 ARCO ALASKA, INC. P.O. Box 360 Anchorage, Alaska 99510 Well Number: 11-7 Location: Prudhoe Bay,' North slope, Alaska Type of Survey: Directional Single Shot Date: 16-Feb-82 Method of Computation: Radius of Curvature Surveyor:-B Forguson Job Number: A0182D0244 Attn: Bob Hines Dear Mr. Hines, I am enclosing the original and one copy.of the Directional Single Shot Survey run on the above mentioned well. We wish to take this oPportunity tD thank you for calling on our services and trust that we may continue to serve you in the future. Sincerely, SHYAM TALWAR District Manager ST/bb cc: file enclosure Directional Drillers/SubSurface Surveyom/Instrument & Tool Rentals/SaleslWofldwide ,,,,_ ARCO ALASKA, INCo Do .1.:1., WEL. I... NO I.l,.~,.~ J 0 D NO; A 0:1. ~: .... lj 0,:. 4 4 F'F;:UDHOE BAY, NOI:;:TH SI...OI'"'I![, AI...ASKA r:SS, O- 9 :..fi>"~,-]qr:'; · . ,.,, RIGI ROWAN 35 ........, "'DECL'INATION 1 ~.~0' ..... 1./~.4 I. E.b.:i ..... '-" I::.Ao~I';""'" ''; ........................................................... .~.~...,. ......................................' RA'I)IU,S OF CURVATUF;:E NE'I'HOI) . · /F¢CO ALASKA, .INC. :'RUDHOE BAY, NORI'H o .'" ,aL. OFE., AL. ASKA "~ '1 (' ") .JOB NO~ A018,~.1.~,~44 COMPUTATION F,-.,bc.- HO, , 1 'i~'"H E Zi~Tt-.."--- 29 . 4 ,~ 17 -. F' E I') -.. 82 I'1< I.J'i;:. ' ..... ; ............. I Ii:ASLJRED DRII::"I" DRIF'T COUI:;:SI!i: VERTICAl.. VER'1'ICAI... SLJBSE:A R E C T A N O U I.. A I:;: C L. 0 S LJ I:;: l!i: .I) C)(31...EG I) E F"1' H A N G !.. IE. I) I IR I: (.; '1' I 0 N I... I..'i; N ii:; T I..I I) E f:' '1' Ir.! S E C T I C) N T V I) C 0 0 R I) I N A T E S l) I S T A N C E D I 1:;~ E C 'l' I 0 N S E V E F( I T "FEEl' ............. D-Pi ......... D ....... 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A F*E'H~OI.ANE COh-ff~NY 6592, 32 0 N 20 0 W J. 89. 6350.23 1064,6;~ 6288.23 959.97 N 470.22 W 1'068,95 N 26 6 o~64, ~:I.'J. 5 'N ,::0 O'""l,J ...... E~72, 6'6'6' 6";"9 9 ......... 1~.o,.¢, ?4 6604. ~ ? . 114 ......... ~ .................. *' . ~.. ~.~ 7 7119. 28 45 N 25 0 W 155. 6801.2J. ].3~:f2,51 67S9.21 1214.84 N 566.58 W ].~40.46 N 25 0 72].0. 27 45 N 29 0 W 9:1.· 6881.~7 1375.45 6819.37 ].25E~.21 N 586,13 W 1383.50 N 25 -"7~'4"~ ..... 25-i['5~' FF'"D9 ....... 0 .... W ....'4'3~", ......... 72~&'9'~74 ...... ].'5~'8~'9"4---7207;7~'---I-422VS~--N-- ~BD~~l~7~7'¢~N-'25" -4-0.--7ET-0 .... 7'1%72.8~N-'3~4 -' 5 4 ..... W .......... ]:-';'"53-'- --60,47 W 105.61 N 35 42 I,,I 0.21 1,4 0.30 H ..... 0 ':;- :I.'5~ 1.75 ~.~; ">/~ ..... 0.94 0..4 ], 0";'23 '~O 0 · 0 0 l,,J O. 20 ..... l,; '2 . '28 W 2.35 '%/ ............ 0-';'58'~ ~,.,.¢02. 24 45 N 30 0 W 158, 74:1,2,94 1635.68 7350,94 1480,68 N 712,89 W i64J,36 N 25 43 1,] 0·41 .... 8'208'; ........ 21 .... 45"'"N' 29 ..... 0 "W ............ 40'6;' ........... 7785";"9'~ ....]7795";'85 .......... 772~'~2'3 ........ 1';320";-1'5-'N ......... 7'9'178'O-"W~TE~'O'E~-,'"28 .......... N'-26 - 3 W 0 .'75 ..... ' lo,.. : ,..c~ 14 O, 8926. :L 5 15 N "; = 8466.46 20':> '> 8 "" ''> '> 895 '> ' ,,, 0 ~ 718, ,..,,..88 404.46 ,:.. 99 N ,.J. 5 ~ ,,.030.9~ N ? o, 92 9299, 14 0 N 25 0 W 373. 8827.36 2116.50 8765,36 1908.35 N .934.95 W 2J. 25.07 N 26 6 W 0.34 FINAL. CL. OSLJRE - DIF,:E:C'T'ION: N '26 DI'ZC'.~S' 6 HINS 5 ,:> .::. [., o W · ................ "3" ~"~ .................... DISTANCE:, ,~..[ ,:.,... 07 F.E.E. 1 DRIFT CHART'S I-~EL..A1E. IJ DATA FILE · .~I";:CO AI...ASKA, INC, ils .l 1~ WF'LI... NO: 7 D,S,g . JO[~ NO,' A01~:.[0,...44 :'RUDHOI: BAY~ NORTH SI...OF'E~ AL. ASI<A ;URVEY FILE NUMBER 12:2 BOTTOM HOI_IE ASSEMBLY ~AI. UES U~,I=I FOR OEPTH ARE MD ~ , DEPTH [ ESuRIPTION 0.00 '~ '~ ........ i;" · ...................... ,.~6o0, )0 ' 7 S/'4'""'DYNA 4025000 oLIGI-IT ANGL. E 4981,00 ANGLE BUILI) '" 5S7:[ ~00-'"' ................. PACI<E:D' HOLE 65SS.00 AUGI..E DROF' ASSEMBLY 7047,00 7 3/4" DYNA DRZLL. "7170';00 .................... ~NGLE:' DROP ASSEHBL. Y 7877.00 ANGI...E DROF' ASSEMBLY 8S94,00 ANGLE: DROF' ASSEPiBLY VAL. UI:S USI!:'D F'OR DEF'TH ARE: MD , D A Y D E F' T H , · 0o00 2675,00 '3790']'00 ........................... :~790, O0 3790,00 4800";'(f~Y ........ 10 7J. 70,00 11 -'c ,=' ' . 786,.,,00 ........... ':~ .................... ~ ~..~: J., (;, o ................................... 13 9299. O0 - 0 ('~ '" I.J o I::. D D V ~ L. LJ I::. ,.~ F:' 0 R E F:' T I"1 A R E POUNDS M l'~ DEE P l' FI W E:.' ]: G I-'1T 0.00 0.00 :f660 . O0 O. 00 4025';-00' .............................. gS. 00 ............ 4981.00 60.00 5:~-/1. O0 65. O0 6,.__~. 06 .......... : .................. 60 ;00 70-47.00 0.00 7170. O0 50.00 . ......................................... ~;S'TO0 ....... I:iE i5T H ................. R. F'-.' H.. ' ............................................................................................................................................................................................................................................ Of '60. ~25. '-4981'] 5371. 6533. "'7047'* 7170.00 7877.00 9010.00 oo 0'750- ...................... I 00 O. 00 00 ]. ":' 0 ,... 0 . 0 0 0 ........................ :1:,..,=' 0'. 00 ...................... O0 1 ~:' o0. O0 O0 120.00 00 ................................ 0'.'00 ..................................... :1.50.00 140.00 1'40;0'0 ............................... 70.00 .% ~E~TH DATE Purpose of Assy. /~/l~/'orr SURVEYS' FOR' THIS' ASSY. 3,~ (,,,? DRILLWITH WEI~3HT RPM Bit type~/~ & Knozzle Size Hours on Bit. . COMPA, ........ DEPTH · DATE Purpose of Assy. SURVEYS FOR THIS ~SSY. .o DRILLWITH RPM / J~ ~ PUMP & Knozz!e Size Hours on Bit- ,. ) ':.~:.::' DATE =~- ,..5'- ~ ~. S'URVEYS' FOR THIS ASSY. 22 ° ,,v- .z ~- ~ DRILLWITH ' WEI~3HT RPM PUMP & Knozzle Size ! Hours on Bit · ." ~?./~ ~.~ _ // DEPTH ~ ~ '~ / Purpose .of Assy.~/~ ~URVEYS FOR THIS' ASSY. DRILLWITH ~ ~no~ S~e Hours on Bit'.' DATE SURVEYS' FOR THIS ASSY. DRILLWITH WEIGHT ,. PUMP ,,, 3 ,5'- & Knozzle Size Hours on Bit - /~-3/ Purpose- of Assy. - ! S'URVEYS' FOR THIS 'ASSY. DRILLWITH · ' WEt~GHT_ · RPM PUMP & Knozzle size Hours on Bit-.' DEPTH DATE Purpose-of Assy. SURVEYS' FOR THIS A'SSY. DRILLWITH .p~ ~. //,o// & Knozz!e Size Hours on Bit' We!-i = Purpose of Assy. ~POp · SURVEYS FOR THIS' ~SSY. DRILLWITH w~,~HT 5'",~/. PUMP '.,.~ ..~'-~;, Bit & Knozzle SiZe Hours on Bit. Purpose of SURVEYS' FOR THIS' ASSY. DRILLWITH PUMP _ Bit & Knozzle Size Hours on Bit- Purpose of Assy. SURVEYS' FOR THIS'ASSY. ?J?? & Knozzle Size Hours 'on Bit - .. : . ~ .'.. . . ~ . . : I " .~ I : ,'- ..,'.:: . , ". ' .' i" l! I i'l! 1 I Z q ;. .' " , . """ I" . .,. )'~ . " , ' ¡ ,,-,,111"1 _U' " " "", ,:.-:.:! L ,-it.; " I I , : ' ' .' C:""'2 '.('':- c'''''r ('Þ''' "...t::'. ' .OT "'0'-'" .. ' ¡ . .J t) , . ~~ 7 G ..j;.) . '::J. t - ~H'; , :' ~.. .:, ':" :- . ¡.- "-'--"---"-1-'-~---"-"I'------I----"_._-- ----'-.-'----'ï 0 '';-:''':-'''-'--'~--:~-'- : I . I' I I, , J ' , , ': " I::',:,'",' ";':':' ' ; , , , , ,: \ ' ",",'" ,',' :' ,'C' ',', ,C':' ,':;':' " ": ' , : ' " " '.. ",.. LoaD I ' : ' " ' ' ' - " " " , ",- " : '; '; \ .. ,I , ,'-,..".. ' : ,,' ': " ' " , " , , i ,," '" ..' , ..' : " . . "", " . . .' . . : : : ' , :.', '.' " "r' I' ."'" .."1. . : , , " : ,,-:,," : ,:::' :,,' ," .. ...... .,.. ,-I . ... ..... - '" .. ..' .., . .' . ' ¡. .' I :. . : I'. . ' . I... . ,~ , " : ' .,' .. ,'.' .¡' ';': ,,", , ' - ' ,:' , --,: - I .. , , , ',' " ,~-í""T-------- ----'-- ,'.. 10GOO -¡----:---- ,-----.,--- ----.:.i:: "', I " ". . .:, ' I ; , .. , . I " ' 91 "I ;, '-:: :;,~' ,'.' .' Ii. . " I'. '. . . ~ I ~ .' '," '." "~'" :' '1 I '.' " ',::" ': ", ' 1 ' ! ¡ ,'. '" ' .. . f !:-.-""... ".:""," f 'I'" ' ," ,,:' ¡ ¡. "i ,I ¡~ ' .:' ~:''.' ,;:: > i: '! i,' ' ',(' :\:::;"" :' ", .' ~I ! ~", ":,, :,:' t I : . Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. Operator,'We~I1 Name and Reports and Materials to be received by: Date Required Date Received Remarks Completion Report Yes ~/_3~_F~Q, ~,.~ ~, · , ..... , ~re ~ips ,~~~ '. ....... ~ ~ Core ~scription. ~' [ ~ Registered Su~ey Plat /~ ~ Inclination Su~ey ~¢ .-- ~ {/~ , .... ,Drill St~ Test Ro~s /~ ~e.~ ~ ..~;~ Pr~u~ion T~t Re~rts ~ ' ~ ARCO Alaska, Inc.f Post Office {., 3{50 Anchorage, ~.~ .,aska 99510 Telephone 907 277 5637 April 1,1982 Reference: ARCO OPEN HOLE FINALS D.S.ll-7 2/15/82 FDC Run 1 5" D.S.ll-7 2/15/82 FDC/CNL ' ~Ru~ 1 5" D.S.ll-7 2/15/82 BHCS Run 1 2" & 5" D.S.ll-7 2/15/82 DIL/SFL Run 1 2" & 5" D.S.ll-7 2/15/82 Cyberlook Run 1 5" Please sign and return the attached copy as receipt of data. Mary F...Kellis North Engineering Transmittal # 86 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON ARCO Atasxa. ,nc. Js a suO,~14.;lary of AHar~tlcR~chfielclCompany EXXON MOBIL GETTY D&M GEOLOGY STATE OF ALASKA Nssk~ 0il & Gas Cons. Commission ARCO Alaska, Inc. Post Office ~'. 3{50, Anchorage. ,~, 9-3510 Tele.Dhone 90~," _77 5637 March 30, 1982 Reference: ARCO DIRECTIONAL SURVEY DATA D.S.15-3 3/9/82 to 3/21/82 Single-Shot D.S.14-29 3/13/82 Gyroscopic D.S.13-6 3/2/82 Gyroscopic , ~i~iS.I1-7~,'~ 2/27/82 Gyroscopic D.S.16-1 3/6/82 Gyroscopic Job No. 0382-021 Job No. AO382G0416 Multi-Shot Job No. A0382G0404 " Job No. A0382G0407 " Job No. A0382G0408 " Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal # 75 DISTRIBUTION NORTH.GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M GEOLOGY STATE OF ALASKA ARCO Alaska, Inc. ~ Post Office BI,, ,dO Anchorage. Alaska 99510 Telephone 907 277 5637 March 22, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Si r: Enclosed are Well Completion Reports for the following drill sites: 13 -20 15-1 1A-14 1A-15 WS 23 Also enclosed are monthly reports for February on these drill sites: 11-7 13-23A 14-29 14-30 15-2 Eileen No. 1 Oliktok Pt. No. Copies of the DS 13-20 gyroscopic survey were sent to you under separate cover. Si ncerely,/i P. A. Van Dusen Di.strict Drilling Engineer PAV:JG/hrl Enclosures GRU2/B14 Gas ()or~s Commiss~!-~ ARCO Alaska Inc is a $~bsidia,y ~f atlanticR~c~]lie'dCompany , /-- STATE OF ALASKA .. ALASKA{ _AND GAS CONSERVATION Cf( ,VlISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 81-177 3. Address 8. APl Number P. O. Box 360, Anchorage, AK 99510 5o-029-20687 4. Location of Well at surface 253' FNL, 81' FEL, Sec. 23, T11N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 62' RKB ...... AFII~ 28325 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. 11-7 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool For the Month of February ,1982 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 0400 hrs, 01/31/82. Drld 17-1/2" hole to 2675'. Ran & cmtd 13-3/8" csg. Drld 12-1/4" hole to 9410' Ran logs. Drld 12-1/4" hole to 9440'. Ran & cmtd 9-5/8" csg. Ran 5-1/2" completion assembly. Displace well to diesel. -Closed SSSV. Secure well and released rig @ 2200 hrs, 02/20/82. See Dri 11 ing Hi story. ~3. Casing or liner run and quantities of cement, results of pressure tests 20", 91.5#/ft, H-40 conductor to 80'. Cmtd w/275 sx Permafrost II. i13-3/8", 72.0#/ft, L-80 csg w/shoe @ 2659'. Cmtd w/2700 sx Fondu & 400 sx Permafrost 9-5/8", 47.0#/ft, L-80 & S00-95, csg w/shoe @ 9429'. Cmtd w/788 sx Class G. See Drilling History. 14. Coring resume and brief description N/A. 15. Logs run and depth where run BHCS/DIL/SP/GR FDC/CNL/GR/Cal CBL/CCL/GR ii~~6. DST data, perforating data, shows of H2S, miscellaneous data N/A A!:zska 0il & Gas 0ohs, Commission Anchor~.g~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED . ,,- TITLE Area Drilling Engineer NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 DS 11-7 Drilling Hi story NU 20" Hydril and diverter. Spudded well @ 0400 hrs, 01/31/82. Drld 17-1/2" hole to 2675'. Ran 64 its 13-3/8" 72#/ft, L-80, BTC csg, w/shoe @ 2659'. Cmtd 13-3/8" csg w/2700 sx Fondu cmt & 400 sx Permafrost C. ND 20" Hydril and diverter. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 11.5 ppg EMW - ok. Set 155 sx Class G cmt balance plug on top of fish (200' plug). Drld 12-1/4" hole to 9410'. Run BHCS/DIL/SP/GR, FDC/CNL/GR/Cal. Drld 12-1/4" hole to 9440'. Ran 183 its 9-5/8" 47#/ft, L-80, BTC csg & 48 its 9-5/8", 47#/ft, S00-95, BTC csg w/shoe @ 9429'. Cmtd 9-5/8" csg w/788 sx Class G cmt Instld 9-5/8" packoff & tstd to 5000 psi - ok. Tstd csg to 2000 psi - ok. ~irc hole clean @ 9380' PBTD. Ran CBL/CCL/GR. Arctic packed 9-5/8" x 13-3/8". Displaced well to NaC1. Ran 5-1/2" completion assy w/tail @ 8702'& pkr @ 8590' Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 50(~0 psi - ok. Displaced well to diesel. Dropped ball & set pkr. Tstd tbg to 3000 psi & annl to 200 psi - ok. Tstd tbg to 200 psi & annl to 3500 psi - ok. Closed SSSV @ 2255' MD. Instld tree cap & tstd to 5000 psi - ok. Secured well & released rig @ 2200 hrs, 02/20/82. and ~-H"om crd cS' -.,q'~c clyr~-ddll. JG:hrl 03/19/82 GRU2/A27 ARCO Alaska, Inc.~( Post Office {r 360' Anchora(~e, ~,aska 99510 Telephone ,307 277 5637 'March 17, 1982 Reference: ARCO DIRECTIONAL SURVEY DATA 2/16/82 Single-Shot Job No. AO182D0244 . . . D.S.I3-20 2/19/82 Gyroscopic Multi Job No. AO282G0285 ~eas~ s~gn and return the 'attached copy as receipt of data. -. Maryi¥. Kell~s North Engineering Transmittal # 37 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO' MARATHON CHEVRON ARCO Alaska. inc. Is a suD~;~.-'~ry oF AHantlcRichfJe!cCompany EXXON MOBIL GETTY D&M GEOLOGY STATE OF ALASKA Gas Cons. Commission ~chorage ARCO Alaska, Inc. Post Office( Anchoraae?~. ,ska 99510 Telephone 907 277 ~637 March 11, 1982 Reference: ARCO MAGNETIC TAPE & LIST D.Soll-7 2/15/82 Tape # 62573 ~~Please sign and return the attached copy as receipt of data. Mary F. Kell±s North Engineering Transmitt:al # 26 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY PHILLIPS D&M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON ARCO Alaska, Inc. f Post Office ~ 260 Anchorage. Alaska 99510 Telephone S07 277 5637 March 24, 1982 Reference: ARCO CASED HOLE FINAL LOGS D.S.14-29 2/29/82 CNL Run 1 2'"& 5" 2/26/82 CNL Run 1 5" D.S.12-14 2/23/82 CNL Run 1 2"/5" ~.!!~'~'~ 2/19/82 ACBL/VDL/GR Run 1 5" D.S.13-20 2/17/82 CNL Run 1 2"/5" D.S.15-1 2/17/82 CNL Run 1 2"/5" Please' sign and return the attached copy as receipt of data. Mary F. Kell~is North Engineering / · .. · , Transmittal # 59 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M GEOLOGY STATE OF ALASKA ARCO A!.ska. 0i~ & Gas Cons. Commission '" Anchorage ALASKA OIL AND GAS CONSERVATION COMMISSION Chat Chattert~//~ ~ Chairman Thru: Lonnie C. Smith Commi s s ione r Bobby Foster Petroleum Inspector February 5, 1982 Witness BOPE Test on ARCO's LS 11-7 Sec. 33, TllN, R15E, UM Pe rn'~ t #81-177 T_u~esday,._Februa~ry_ _2, ..1....9.8.2 -While standing by for equipment replacement on ARCO's West Sag #23 I went to DS 11-7 and witnessed the BOPE test. As the attached BOPE inspection report shows there was one failure. The door gasket leaked on the upper pipe rams. This was replaced and retested. In summary I witnessed the BOPE test on ARCO's DS 11-7. · O&G #4 ~ .4/80 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report I nspectori'5 ~.~d~ Operator Well Date Well ~, .~ .... ~/- Representative Permit #_ .~/ .... Location: S~c 3S T/./~. R/~'~X{}/~' /~asing Set @ ~~ ft. Sontracto .3-: e re e tat v . Location, General ~, Well Sign ~_/ General $ousekq~ping p .~ Reserve pit ~ Rig ~ BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve / . Test Results: Failures Test Pressure ACCUMULATOR SYSTEM Full Charge Pressure ~%1~6 psig Pressure After Closure /~O psig 200 psig Above Precharge Attained:-- mi~ sec Full Charge Pressure Attained: ~ mina'-sec Controls: Master ~-/~ 3 Remote¥_~ Blinds_switch cov_.e_r_~_~_ Kelly and Floor Safety Valves Upper Kelly / Test Pressure Lower Kelly / Test Pressure Ball Type / Test Pressure ~/ Inside BOP / Test Pressure Choke Manifold~ Test Pressure No. Valves No. flanges ~ Adjustable Chokes // / ~, Hydrauical~ly operated choke / Test ....... Repair or Replacement of faiied equipment to be made within --~ days and Inspector/Commission office notified. Remarks: '~ ~9/%2~. ~,"/o~ ~,~ Distribution orig.' - AO&GCC cc - Operator cc - Supervisor Inspector, ~,.~~'"1 '/: December 1, 1981 Mr. Charles E. Ross senior Dril ling Engineer ARCO Alaska., Inc. P. O. Box 360 Anc~orage, AlaSka 99510 Res Prudhoe Bay Unit DS 11-7 ARCO Alaska Inc. Permit No. 81-177 Sur. Loc. I 253fFNLt 81'FELt Sec 33, T11N, R15E, UM, ~tt.~ole Lo~.: 1376tFSL, i070~FEL, Sec 28, TIlN, R15E, En=losed is the approved application for permit to dril. 1 the referenced well. ~ell samples and a mud log are not r~uire~. A continuous dtrectiona! survey is as per 20 AAC 25.050(b){5). If available, a tape ~onta the digitized log information shall ~ s~tt~ on all-logs for ~ing exce~ ~ri~ntal logs, velocity .su~oys and Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are. subject to AS 16.50.'870 and the regulations promulgated thoreunder (Title 5, Alaska Administrative Code). Prior. to commencing operations you may be oontacted by the Habitat Coordina~ores office, Depart.-ment of Fish and Ga~e. Pollution of any waters of the State is prohibite~ by AS. 46, Chapter 3, Article 7 and the regulations promulgated~ thereunder (Title 18, Alaska A~l~inistrative ..Code, Chapter 70) and by the Pederal Water Pollution Control Act, as amended. Prior to Mr. CharIes E. Ross Prudhoe Bay Unit DS 11-7 -2- December 1, 1981 commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the Commission may be present to witness testing of blowout preventer equipment ~fore surface casing shoe is dril!ed. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Ve~f truly yours, H. Hamilton Chairman of BY ORDER OP. IH.H CO[vI.~SSION Alas~ Oil & Gas Conservation Commission Enclosure cc~ Department of Fish & Game, ~abttat ~ectton w/o encl. Department of Environmental Conservation w/o/encl. HHHibe ARCO Alaska, Inc.[ Post Office [~ . 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 18, 1981 Mr. Hoyl e Hamil ton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS ll-7 Permit to Drill Dear Sir: Enclosed please find our application for Permit to Drill DS ll-7 and the required $100 filing fee. Attachments to the application include an as,built drawing, a plat' detailing the section and plan views of the proposed wellbore, a proximity plat showing the subject wellbore's position to the nearest well drilled, and a sketch and description of the BOP equipment and testing procedure, including anticipated pressures, As confirmed in previous corre- spondence from your office, the requirement of using a surface hole diverter system on this well has been waived. rs, C. E. Ross Senior Drilling Engineer CER: 1 tc Attachments ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany (~/,._ STATE OF ALASKA i~.i ALASKA AND GAS CONSERVATION CO ,IISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL ][] lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVELOPMENT OIL [~ SINGLE ZONE [] DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P.0. Box 360 4. Location of well at surface 9. Unit or lease name 253'FNL, 81'FEL, Sec. 33, TllN, R15E, UM Prudhoe Bay Unit At top of proposed producing interval 10. Well number 1219'FSL, 975'EEL, Sec. 28, TllN, R15E, UM DS ll-7 At total depth ~.. ~ ~r~.~l~. i~- ~ ~,~ ~%~r'~ \'v-~-~l ~"~-~ 11. Field and pool 1376'F~L, 1070 FEL, sec. 28, T'llN;RIEE, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. Prudhoe 0i l Pool 62' RKBI ADL 28325 12. Bond information (see ~0 AAC 25.025} Type Statewide Surety and/or number Fed. ]:ns. Co. #8088-26-2~mount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed' NE Deadhorse, Alaska miles 3904 feet we. @surface 100 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 9261'MD & 8966'TVD feet 2560 1/6/81 ~::~ 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 3761 psig@ Surface KICK OFF POINT2700feet. MAXIMUM HOLE ANGLE 1 8 oI (see 20 AAC 25.035 (c) (2)4422_psig@ 8966ft. TD (TVD) . 21 Proposed Casing, Liner and Cementing Program INSiZEIN 1 bsCASING AND LINER 'FT FT SETTING DEPTH FT QUANTITY OF CEMENT. Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data} 32 20 94 H-40 ~elded 80 32 I 32 112 112 250 sx permafrost 17½ 13-3/8 72 L-80 Butt 2568 32 ~ 32 2600 2600 2300 sx Fondu + 400sx I · 12¼ 9-5/8 47 L-80 & Butt 9231 30 ' 30 9261 8966 STG I - 700sx Class'"[- S00~95 ~ I STG 2 300sx PF t - I I 22. Describe proposed program: .ARCO Alaska, :Inc. proposed to directional],y drill this we]l'to 9261"MD (8966'TVD) to produce the Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8" 5000 psi RSRRA BOP stack will be installed and tested to 5000 psi The BOP equipment will be pressure tested each week and operationall~v'tested each trip. A string of 5½'" 17#, L-80 tubi.ng, packer and necessary provisions for subsurface safet~v equipment will be run. A non-freezing fluid will be left in all uncemented annuli within the perma- will be submitted when the well is to be perforated. K I;;~ L. I v L- I,' NOV 2 ? 1981 SIGNED 23. I hereby ~~ tr~ the best of my knowledge Alaska 0|, & Bas O0ns. C0~ui-u's~'0u Anchorage T'TLESr. Drilling Engineer DATE · The space below for Commission use CONDITIONS OF APPROVAL Samples required Mud log required Directional Survey required APl number [-I Y ES [~NO [--I YES (~[N O [~-Y E S []]NO 50- O '~- ~ -~,~ Permit number Approval date ~(~ - / 7~ 12/01/81 I SEE COVER LETTER FOR OTHER REQUIREMENTS , APPROVED BY ~ ,COMMISSIONER DATE Dec6mber 1, 1981 by order of the Commission Form 10-401 Submit in triplicate Rev. 7-1-80 ~oo s -r llkJ ~lr3E, i..t.M.. i HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS AN AS-BUILT SURVEY MADE BY ME, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT, 'AS OF: D.S. ti-CONDUCTORS 6-7 RS-BUILT LOCATIONS ALL COOROS=RLRSKR ZONE 4 '11/6 LAT= 70 16 13.817 LONG=148 19 17.966 Y=5,951,353.08 X= 787,586.78 CELLAR BOX ELEV=27.8 1147 I I I II III II I I I IIIII LILT= 70 16 14.978 LONG=I48 19 18.684 Y=5,951 , 46:~ . 62 X= 787,478 . 8;3 CELLAR: BOX ELEU=28.! RECEIVED NOV 2 ? 198t ~aska 0il & Gas Cons. Commissio~ Anchorage P. 5. I| CO~DUCTOt% A%-ISU&.'T - WELt.% G ~ ""1 I I Ill I I I ~ll lllll II I I II Il Ill II AtlantliCRichfi®ldCompany 4~ DATE: IDRAWlNG No: NORTH AMERICAN PRODUCING DIVISION [O/l~.4/&l ALASKA DISTRICT- ~RUDHOE BAY. III J II I II I IIII I I III PREVENTER BLIND'RRMS PIPE RRHS DRILLING SPOOL . . , 3~ PIPE RRHS 4. 5, 4422 - Maximum Anticipated ' Bottom Hole Pressure, 3761 - Maximum Pressure to which BOP's could be ~;b~:ot~; aCal ~sUl~ut~l e i;** * ~ at reservoi'gr pressureg to ~ rise w/o expanding but cooling to 8Q~F, psi, ' .9. lO. ll. 12. 13. 14. 15. 16. 17. 13-5/8" BOP STACK DIAGRAM Accumulator Caoacitv Test Check and fill accumulator reservoir to proper level with hydraulic fluid. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. Observe time, then close all units simultan- eously and record the time and pressure re- maining after all units are closed with charging pump off. Record on IADC report. (The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure.} 13-5/8" BOP Stack Test .. Fill BOP stack and manifold with a non- freezing liquid. Check that all hold down screws are fully re- tracted. Predetermine depth plug will seat & mark running joint. Run test plug on drill pipe and seat in wellhead. Run in lock down screws in head. Close annular preventer and chokes and Bypass valves on manifold. In each of the following tests, first hold a · 250 psi low pressure test for a minimum of 3 minutes, then test at the high pressure. Increase pressure to 3000 psi anJ hold for a minimum of 3 minutes. Bleed pressure to zero. Open annular preventer and close top set of pipe' '~ams. Increase pressure to 5000 psi & hold for at least 3 minutes. Bleed pressure to zero.' ClOse valves directly upstream of chokes & open .chokes. Increase press, to 5000 psi & hold for at least 3 min. Bleed pressure to zero. Open top'set of pipe rams then close bottom set of-pipe rams. Increase press, to 5000 psi below the bottom set of pipe rams & hold for at least 3 minutes. Test remaining untested manifold valves (if any) with 5000 psi upstream of valve and zero pressure downstream. Bleed pressure to zero. Open bottom s~t of pipe ramq. Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for at least 3 minutes. Bleed pressure..off all equipment. Open blind rams. Make sure manifold & lines are full of non-freezing liquid and all valves are set in drilling position. Test standpipe valves to 5000 psi. Test Kelly cocks and inside BOP to 5000 psi with Koomey pump. Check operation of De Gasser. Record test information on Blowout preventer test form. Sign and send to Drilling Super. Perform complete BOPE test once a week and functional operate BOPE daily. CHECK LIST FOR NEW WELL PER>~ITS Company Lease & Well No. ? .> ITEM APPROVE DATE (2) Loc~-/:,~ U-. :: .... /(2 thru 8) (3) Admin thru 11) (4) Casg ~ (12 thru 1. Is the permit fee attached ........................................ 2. Is well to be located in a defined pool .................. Is well located proper distance from property line ...... Is well located proper distance from other wells ......... Is Sufficient undedicated acreage available in this pool Is well to be deviated and is well bore plat included ... .. Is operator the only affected party ..................... Can permit be approved before ten-day wait ............... Be 4. 5. 6. 7. 8. YES NO REMARKS e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. Does operator have a bond in force ................................. ¢~ Is a conservation order needed ....................................... ~~ Is administrative approval needed .................................. .. Is conductor string provided ........................................ .~__ Is enough cement used to circulate on conductor and surface ......... ~ Will cement tie in surface and intermediate or production strings ..<~j~ Will cement cover all known productive horizons ..................... ~ . Will surface casing protect fresh water zones ....................... ~ Will all casing give adequate safety in collapse, tension and burst..~ Is this Well to be kicked off from an existing wellbore ............. ~ Is old wellbore abandonment procedure included ~n 10-403.... ~ ....... ~.. __---- /~.~t). Is adequate well bore separation proposed .......... ...... ~ - (5) BOPE~ (21 thru 24) (6) Add: 21. 22. 23. 24. 25. Is a diverter system required ....................................... __ ~ ¢/Z/~ { Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating - Test to .f-~O psig ..~__ Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. f~,,~:~ Additional requirements Additional Remarks: . Geology: Engineering: wvAHW~~JAL ~' _~ LCS--JC~:BEW~,JKT j~___~RAD~ - /, rev: 03/10/8i · INITIAL l GEO. UNIT iON/OFF POOL CLASS STATUS AREA NO. · SHORE Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIXi .. No Special'effort has been made to chronologically organize this category of information. · Company. '~ ARCO ALASKA, INC. Well .D.S. 11-7 Field PRUDHOE BAY · County, State N. SLOPE, ALASKA Date 2-26-82 Curve }~ame (Abbrev.) Standard Curve t~ame Logs U~ed Scale OR ~ ~a~a ~ay ....... C~-~u!t~paced 0-:l oo, {oo-2,,o0 " 0-10 ,.. CCL ., Casin,~ Collar Locator t ......... LSN, . L?ng Spaced ,, " ,, 071250 ,, SSN _ Short Spaced " 0-1000 ~ CN . Compensat, ed Nuetron ....... 60-0 ) , , ~ ..... ,. , , . ~ , .. ,, , , ,,, ... ,, ,1 ,. , . . PAGE 3. RCO ALASKA PETROLEUM COMPANY 8760.0 392,9 327,8 3~.63 108,2 0,80 8780,0 32~',1 3~+,7:1. 3.33o~ 0,80 300.9 ~.3o 8800,0 $§?.0 288.0 37,10 139,5 0,80 ' ;57 3., 5' 8820,0 555,5 281,9 35,55 130,5 0,80 .... 55q.., 7 302,1 39" q.l 0:1;:76" . PASE 2 ~CO ALASKA PETROLEUM COMPANY 9~ 0,0 3~ '6 31q..3 33,38 39.0 0.80 '--~-;-~---~95" ' ' "~' ~."' ~'";~ "' .................................... .~.:____ ........ , . . . ~ ~<~>,~ q-11.2 3~6.7 ~7.98 ~R.3 0.80 7.~ 329.0 30,29 ~7.9 0.80 ~~- ~.2 P8,97 52,2 0,80- - 9300.0 9320,0 q.:l.O.5 321,0 ~)9.23 6,2,7 0,80 q. 25.0 3~1,8 30,18 70,2 0,80 '~~2 ~5.5 ~9.93 ~e.8 0.80 8~ -9- .................................................... ~-i~'-;-~ ..................... :~-3-;"~' ~' ....................... ~; ~ .......... ~%-~b- ALASKA INC PRUDHOE BAY Run 1' 06 - August - 1992 DLLIACICNIGR RECEIVED SEP 2 5 1992 Naska Oil & Gas Cons. Commissio An~rage Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD RUN1 102262 BRAD ESARY HERNANDEZ / D.S. 11 - 7ST 500292068700 ARCO ALASKA INCORPORATED ATLAS WIRELINE SERVICES 24-AUG-92 RUN2 MOSTELLER 33 liN 15E 253 RUN3 81 64.70 63.70 24.00 OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 8274.0 DLL/AC/CN/GR CIRCULATION STARTED: 14:30, 05-AUG-92 STOPPED: 15:00, 05-AUG-92. ORIGINAL R.K.B. 62.0'. LOG TIED TO DUAL INDUCTION DATED 15-FEB-82, FROM 8272' KOP TO 8150'; SEE GR ON CN REPEAT SECTION. CN HOLE CORRECTION 8.5". AT ARCO ALASKA'S REQUEST; THE GAMMA RAY FROM THE REPEAT PASS WAS SPLICED ONTO THE TOP OF THE MAIN PASS GAMMA RAY FOR THE PURPOSE OF COMPLETE DATA COVERAGE IN THE MERGED FILE. $ **** FILE HEADER **** FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; depth shifted and clipped curves; all runs merged; no case hole data. DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GR BCS 2435 DLL $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA START DEPTH 8272.0 8647.0 8648.0 8648.0 GR (MEASURED DEPTH) BASELINE DEPTH DT 8272.0 8272.0 8653.0 8653.5 8658.5 8671.5 8677.0 8690.5 8700.5 8733.0 8742.0 8744.5 8652.5 STOP DEPTH 9410.0 9460.0 9417.0 9429.0 EQUIVALENT UNSHIFTED DEPTH NPHI LL3 LLD 8272.0 8272.0 8272.0 8653.0 8659.0 8676.5 8700.5 8700.5 8700.5 8757.0 8757.5 8757.5 8758.0 8764.0 8766.5 8784.0 8785.0 8784.0 8803.5 8822.5 8848.5 8850.5 8849.5 8853.5 8859.0 8860.0 8859.0 8860.5 8865.5 8865.0 8885.0 8886.5 8886.5 8889.0 8889.5 8889.0 8893.5 8893.0 8908.0 8908.5 8908.0 8909.0 8925.0 8936.5 8936.5 8940.0 8947.5 8951.5 8951.5 8955.0 8955.5 8956.5 8956.5 8962.0 8968.5 8972.5 8975.5 8977.0 8976.5 8982.5 8742.0 8671.5 8690.5 8733.0 8744.5 8757.5 8757.5 8757.5 8763.5 8766.0 8784.0 8784.5 8784.5 8803.0 8821.5 8847.0 8852.0 8851.5 8859.0 8858.5 8859.0 8885.0 8889.0 8889.0 8889.5 8908.0 8908.0 8909.0 8925.0 8940.0 8940.0 8940.0 8947.5 8956.0 8969.0 8973.5 8976.5 RECEIVED 8955.5 SEP 2. 5 199P. 8 9 6 2 5 ,AJs. sk~1011 & Gas Cons. Commission 8973.5 8977.0 8982.5 8985.0 8988.0 8994.5 9006.0 9006.5 9026.0 9032.5 9040.0 9053.0 9077.5 9078.5 9079.5 9080.5 9088.5 9096.0 9113.0 9118.0 9123.5 9124.0 9129.0 9136.0 9139.0 9139.5 9145.5 9153.0 9160.0 9160.5 9161.0 9171.5 9172.0 9200.5 9201.0 9204.0 9206.0 9209.5 9218.0 9222.5 9226.0 9226.5 9233.5 9235.5 9236.5 9241.5 9242.0 9244.0 9253.0 9266.5 9269.0 9269.5 9275.0 9276.5 9279.5 9280.0 9282.0 9287.0 9295.0 9295.5 9306.0 9314.5 9316.0 8985.0 9079.0 9139.0 9152.5 9160.5 9203.5 9205.5 9209.5 9225.0 9232.0 9235.5 9242.5 9275.0 9279.5 9295.0 9305.5 9006.0 9078.5 9122.5 9145.5 9171.5 9201.0 9205.5 9225.0 9242.5 9276.5 9279.5 9294.5 9315.0 8988.0 9006.0 9079.0 9095.5 9112.5 9128.0 9139.0 9160.0 9171.5 9200.5 9204.0 9235.5 9269.5 9294.5 8994.5 9006.0 9025.5 9032.0 9039.0 9052.0 9076.0 9079.0 9087.5 9095.5 9112.5 9117.5 9123.5 9128.0 9135.5 9139.0 9159.5 9171.0 9201.0 9218.0 9222.5 9235.5 9241.5 9253.0 9267.0 9269.0 9282.0 9286.5 9294.5 9305.5 9315.5 9324.0 9324.5 9325.0 9324.0 9323.5 9329.0 9327.5 9340.0 9339.5 9363.0 9361.5 9365.0 9365.5 9364.5 9366.0 9365.0 9373.5 9374.0 9374.0 9374.5 9374.5 9386.5 9386.5 9425.5 9482.0 9482.0 9482.0 $ MERGED DATA SOURCE PBU TOOL CODE RUN NO. PASS NO. GR 1 6 GR 1 5 BCS 1 5 2435 1 5 DLL 1 5 $ REMARKS: CN WN FN COUN STAT 9323.5 9364.5 9374.0 9482.0 9324.0 9365.5 9374.5 9425.5 9482.0 MERGE TOP MERGE BASE 8272.0 8650.0 8650.~0 9410.0 8647.0 9460.0 8648.0 9417.0 8648.0 9429.0 THE GAMMA RAY CURVE IS A COMPOSITE OF REPEAT & MAIN PASS DATA. FUCT & NUCT WERE SHIFTED WITH NPHI. TENS, TEND, & MTEM WERE SHIFTED WITH LL3. SP WAS SHIFTED WITH LLD. $ : ARCO ALASKA INCORPORATED : D.S. 11 - 7ST : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 11 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR BCS 68 1 2 DT BCS 68 1 3 TEND BCS 68 1 4 TENS BCS 68 1 5 NPHI 2435 68 1 6 FUCT 2435 68 1 7 NUCT 2435 68 1 8 LL3 DLL 68 1 9 LLD DLL 68 1 10 SP DLL 68 1 11 MTEM DLL 68 1 GAPI US/F LB LB PU-S CPS CPS OHMM OHMM DEGF 4 67 465 06 6 4 84 653 71 5 4 20 789 90 0 4 20 789 90 0 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 44 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 116 Tape File Start Depth = 9482.000000 Tape File End Depth = 8272.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 29053 datums Tape Subfile: 2 330 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes RECEIVED S EP 2 5 199~ Almstm Oil & 6em ~ne. ~mmimmion Tape Subfile 3 is type: LIS **** FILE HEADER **** FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 6 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 8149.0 8272.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ REMARKS: CN WN FN COUN STAT GR FROM REPEAT PASS PRESENTED HERE FOR PURPOSES OF COMPLETE DATA COVERAGE. $ : ARCO ALASKA INCORPORATED : D.S. 11 - 7ST : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 3 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH GR 68 1 GAPI 2 TEND GR 68 1 LB 3 TENS GR 68 1 LB 4 4 21 990 60 6 4 4 66 264 36 0 4 4 66 264 36 0 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 5 Tape File Start Depth = 8272.000000 Tape File End Depth = 8143.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 1037 datums Tape Subfile: 3 31 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes 12 RECEIVED SEP 2 5 1992 AIm km Oil & Tape Subfile 4 is type: LIS TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY **** FILE HEADER **** FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 1 5 0.2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8642.0 9411.0 AC 8642.0 9474.0 2435 8642.0 9417.5 DLL 8648.0 9443.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT TEMP GR CN PCM KNJT KNJT MIS DLL FTS FTS MIS AC $ CABLEHEAD TENSION TEMPERATURE GAMMA RAY COMPENSATED NEUTRON PULSE CODE MODULATOR KNUCKLE JOINT KNUCKLE JOINT MASS ISOLATION SUB DUAL LATEROLOG FEED THROUGH SUB FEED THROUGH SUB MASS ISOLATION SUB BHC ACOUSTILOG BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): 06-AUG-92 FSYS REV. J001 VER. 1.0 1500 05-AUG-92 146 06-AUG-92' 9472.0 9468.0 8150.0 9460.0 1800.0 TOOL NUMBER 3974XA 2806XA 1309XA 2435XA 3506XA 3921NA 3921NA 3967XA 1229EA/MA 3967XA 1609EA/1603MA 8.500 8274.0 8272.0 POLYMER/SW/KCL 9.60 MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX' . MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS. $ CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : D.S. 11 - 7ST : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 18 Curves: Name Tool Code Samples Units 49.0 8.5 5.6 156.7 0.261 0.119 0.219 0.000 0.384 0.000 68.0 156.7 68.0 0.0 68.0 0.0 THERMAL SANDSTONE 0.00 8.500 0.0 RECEIVED SEP 2 5 1992 Alaska 011 & Gas Cons. Commission Anchorage API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR AC 68 1 GAPI 2 AC AC 68 1 US/F 3 ACQ AC 68 1 4 CHT AC 68 1 LB 5 TTEN AC 68 1 LB 6 SPD AC 68 1 F/MN 7 CNC 2435 68 1 PU-S 8 CN 2435 68 1 PU-L 9 LSN 2435 68 1 CPS 10 SSN 2435 68 1 CPS 11 ED DLL 68 1 MV 12 ES DLL 68 1 MV 13 ID DLL 68 1 A 14 IS DLL 68 1 A 15 RD DLL 68 1 OHMM 16 RS DLL 68 1 OHMM 17 SP DLL 68 1 MV 18 TEMP DLL 68 1 DEG 4 4 06 969 49 6 4 4 48 852 89 1 4 4 81 285 47 0 4 4 95 558 30 1 4 4 95 558 30 1 4 4 61 094 30 1' 4 4 98 211 23 1 4 4 52 326 75 5 4 4 84 023 70 1 4 4 83 368 34 1 4 4 30 739 95 0 4 4 30 739 95 0 4 4 30 739 95 0 4 4 30 739 95 0 4 4 39 859 45 0 4 4 40 514 81 0 4 4 23 415 80 5 4 4 84 503 82 1 * DATA RECORD (TYPE# 0) Total Data Records: 259 Tape File Start Depth = 994 BYTES * 9482.000000 72 Tape File End Depth = 8642.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 92913 datums Tape Subfile: 4 342 records... Minimum record length: 62 bytes Maximum record length: 994 bytes Tape Subfile 5 is type: LIS RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY **** FILE HEADER **** FILE HEADER FILE NUMBER: 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 6 0.2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8144.0 9408.0 AC 8949.0 9472.0 2435 8937.0 9415.0 DLL 8945.0 9440.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT TEMP GR CN PCM KNJT KNJT MIS DLL FTS FTS MIS AC $ CABLEHEAD TENSION TEMPERATURE GAMMA RAY COMPENSATED NEUTRON PULSE CODE MODULATOR KNUCKLE JOINT KNUCKLE JOINT MASS ISOLATION SUB DUAL LATEROLOG FEED THROUGH SUB FEED THROUGH SUB MASS ISOLATION SUB BHC ACOUSTILOG BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: 06-AUG-92 FSYS REV. J001 VER. 1.0 1500 05-AUG-92 223 06-AUG-92 9472.0 9468.0 8150.0 9460.0 1800.0 TOOL NUMBER 3974XA 2806XA 1309XA 2435XA 3506XA 3921NA 3921NA 3967XA 1229EA/MA 3967XA 1609EA/1603MA 8.500 8274.0 8272.0 RECEIVED $£P 2 5 1992 POLYMER/SW/KCL 9.60 49.0 8.5 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: REPEAT PASS. $ CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : D.S. 11 - 7ST : PRUDHOE BAY : NORTH SLOPE : ALASKA 5.6 156.7 0.261 0.119 0.219 0.000 0.384 0.000 THERMAL SANDSTONE 0.00 8.500 0.0 68.0 156.7 68.0 0.0 68.0 0.0 * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 18 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR AC 68 1 GAPI 2 AC AC 68 1 US/F 3 ACQ AC 68 1 4 CHT AC 68 1 LB 5 TTEN AC 68 1 LB 6 SPD AC 68 1 F/MN 7 CNC 2435 68 1 PU-S 8 CN 2435 68 1 PU-L 9 LSN 2435 68 1 CPS 10 SSN 2435 68 1 CPS 11 ED DLL 68 1 MV 12 ES DLL 68 1 MV 13 ID DLL 68 1 A 14 IS DLL 68 1 A 15 RD DLL 68 1 OHMM 16 RS DLL 68 1 OHMM 17 SP DLL 68 1 MV 18 TEMP DLL 68 1 DEG 4 4 06 969 49 6 4 4 48 852 89 1 4 4 81 285 47 0 4 4 95 558 30 1 4 4 95 558 30 1 4 4 61 094 30 1 4 4 98 211 23 1 4 4 52 326 75 5 4 4 84 023 70 1 4 4 83 368 34 1 4 4 30 739 95 0 4 4 30 739 95 0 4 4 30 739 95 0 4 4 30 739 95 0 4 4 39 859 45 0 4 4 40 514 81 0 4 4 23 415 80 5 4 4 84 503 82 1 * DATA RECORD (TYPE# 0) Total 'Data Records: 412 Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = 994 BYTES * 9479.000000 8143.000000 0.250000 72 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 102593 datums Tape Subfile: 5 493 records... Minimum record length: 62 bytes Maximum record length: 994 bytes Tape Subfile 6 is type: LIS **** TAPE TRAILER **** 92/ 8/21 01 **** REEL TRAILER **** 92/ 8/24 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of exeCution: Mon 24 AUG 92 9:28a Elapsed execution time = 47.29 seconds. SYSTEM RETURN CODE = 0 MAR 1 9 ].~ '~ · Oil & G~s Cons, Comm)ssio~ AFtchora~9 L15 TAPE VERIFIO~I'~ON LVP 009.H03 V~RI['ICATION 6ISTII~31 PAGE i ~* REEL HEADER SEBV1CE NAME :,SER¥1C DATE :82102125 ORIGIN : REEL NAME : RE, EL CONTINUATION # :01 PREVIOUS [4 ~ ~31 : COMMENTS :REEL COMMENTS #~ TAPE HEADER .* S5RVIC~ NAME :6ERVIC DATE :82/02/25 ORtG1V~:~ TAPE'NAME : CONT1NU%~ION # :0! PRf¥IOUS TAPE : COMMENTS :T%PE COMMENTS ~ COMMENTS ~ ~. f'lbE HEADER *~ FiLE NAME :SERV1C.001 SERV10~ NA~E : V~RS1DN # : DATE : Mi[IMUM LENGTH : 1024 FILE TYPE : PREVIOUS FILE : ~, COMMENTS ~# WELL LOCATION = SECTION:33 TOWNSHIP:lIN RANGE:15E #. INFORMATION RECORDS ~* COUN: NORTH SLOPE STAT: ALASKA MNEM CONTENTS UNIT TYPE CATE SIZE] CODE 000 DO0 011 065 000 000 006 065 UNIT TYPE CATE SIZE CODE LVP 009.H03 VERiI, IC.~TION LISTIN3. P~GE 2 RANG: RANGE TOWN: TOWNSHIP SECT: S~]( ~] ON COUN: COUNTY ST~T: STATE MNEM CONTENTS PRES; DII.,O0 1F RECORD Tyi~f 047 ~ RECORD TYPE 047 *.* RECORD I:]PE 047 ~ #* CO 4MENrS ** \ SC ~LUMBERGER \ \ ALASKA COMPUTING CENTER \ COMPANY WELL f~IELD 3DUNTY STATE ATIAi. TIC NiGiHJKiD G[MPANY DRILL SI'BE 11-7 PRU~i.iJI~ BAY NORTH SLOPE ~LASKA jOb # 10707,62573 OIL RUN #1, LOG3ED BOTTOM LOG INTERVAL TOP bOG INTERVAL 15-~EB-82 9389 FT. 2660 FT, UNIT 0(0 000 000 000 000 ~YPE 000 000 000 000 000 000 CATE 000 O05 3O8 OO7 0O6 OO5 SIZE OO7 065 065 065 0.65 O65 CODE O65 LYP 009.H03 VERIFICATION LISTING PAGE 3 CASING-bUGGER BIT S12E TYPE HOLE f'LUID DENSIT~ VISCOSITY PR FLUID LOSS RM @ MEAS. TEMg, RMF @ MEAS. TEMP. RM @ BHT 13 3/8 IN. 9 9389 FT. 12 1/4 IN. LiGNOSULFONATE 10.4 40.0 10.5 5.2 NL 1.42 ~ 68 F 1.22 ~ 68 F 1.70 ~ 68 F .68 {a 180 1~' MATRIX SANDS~O, SE ** DATA FORMAT N~CORD *~ ~NTRY BLOCKS T¥~E SIZE REPR CODE ENTRY 4 1 66 1 8 4 73 6 9 4 65 INC~ 0 ! 66 0 D.~TUM SPE;~f~ICATI,ON BLOCIqS ~4NEM SERV$CE 8~RViCE UNIT AP1 AP1 AP1 ~IPI ]fIIE SIZE PROO~SS SAMPLE REPR ID OR)E~ # LOG TYPE CLASS MOD NO. LEVEL CODE DEPT SPLU DiL ILM DIL 1LD DIL SP KIL GR DIL NPHI FDN RHOB' FDN GR FDN CALl FDN DRHO ~DN NRAT FT 0 I( 0 0 0 OHMM 7 0 0 0 0 4 OHMM 7 0 0 0 0 4 OHMN 7 12 45 0 0 4 NV 7 1 0 0 0 4 GAP1 7 31 32 0 0 4 PU 42 ~ 2 0 0 4 G/C3 42 35 1 0 0 4 'EAPI 42 31 32 0 0 4 IN 42 28 3 0 0 4 '(A(3 4~ 44 0 0 0 4 42 42 1 0 0 4 1 1 1 1 1 1 1 1 1 1 1 6f 68 68 68 68 68 68 68 68 68 68 68 bVP 00~.H03 VERZflCAT1ON LISTING PAGE 4 FCNb FDN GR ,EHC 42 34 92 0 0 42 34 ~, 3 0 0 US/F 60 52 32 0 0 {AP1 60 31 32 0 0 ** DAI'A #* DEPT SP GR NCNb :~411,000 -999.250 125.500 2996,000 DEPT SP G~ NCNb) 9~00.000 -17.016 125,500 299b,000 DEPT SP GR NCNL 9300.000 -52.750 54.969 2602.000 D~PT SP GR NCNb 92C0.0(0 -25.625 76.063 2604.000 DEPT SP GR NCNb 9100.000 -129.125 28.703 2224.000 DEPT SP GR NCNL 9000.000 -95.438 26.656 2970.000 DEPT SP GR NCNb 89¢0.0(0 -116.938 40.188 2466.000 DEPT SP GR NCNb 8800.000 -18.266 186.250 1694.000 DEPT SP NCNb 87C0.0(0 -21.391 -999.250 -399.250 DEPT SP 86[0.0(0 -14.383 Sf'LU ,CALl FCNL SFLU GR ,CALl FCN5, SFLU GR ,CALl FCNL SFLU CALl FCNL SFLU G~ ,CALl FCNL SFLU GR =CALl FCNL SFLU GR CALl FCNL SFLU GR. ,CALl FCNL SFLU GR CALl FCNL $~LU GR 9 1 112 9 112 7 5 1 94 7 86 68 3 1 66 80 2 1 144 1~4 4 1 97 17 1 42 ,1 17 -99 .371 .93B ,250 .000 .365 .938 .453 .000 .563 .039 .789 .500 .531 .484 .117 .000 375 .414 .5O0 .688 .945, .375 .000 .219 .023 .281 .500 .406 .375 .836 .500 .474 {.875 .250 .253 .854 ;. 281 ILM NPHI Dt ILM NP H I DT .1LM NPHI DT ILM NPHi DRHO IbM NPBI DT ILM NPHI '.E BI~ 0 D2' ILM NPHI DRHO DT ~ILM NPHI DT ILM D~HO DT 1LM NPHI 4 4 4 -999.250 28.760 0.086 -99).250 3.850 27.B81 0,088 '999,250 27.234 23.340 0.018 90.188 10.453 26.416 0.016 81.000 132,375 28,369 0.007 9~.563 83.6~5 lt~258 -0.003 81.188 38.188 20.898 0.024 90.563 3.146 45.654 0.018 111,375 6.102 -999.250 -999.250 -999.250 4.527 -999.250 ILD RHOB NRAI GR ILD NBAT GR, RHOB NBAT GR ILD NRAT GR RHOB NRA3~ GR ILD RHOB NRA~ GR ILD RBOB NRAT GR liB[ BOB NRA~ GR ILD RHOB NRA~ GR ILD RBOB I 68 1 68 1 68 I 68 -9~9.250 2.,197 2.461 -)99,250 5.4~9 2.213 2.461 -999.250 33.625 2.41! 2.557 50.039 10.727 2.516 2.771 72.484 932.500 2'173 2.881 30.785 ,1~=1.000 2.381 1.942 25.945 117.250 2.267 2.383 40.023 2.908 2.355 3.908 176.375 5.152 -999.250 -999.250 -999.250 5.129 -999'250 bVP 009,[t03 VERI~PICATION LiSTING PAGE 5 GR -999.250 CALl NCNb -999.250 FCNL OCPT 8500.000 SFLU SP -15,406 OR GR -999,250 CALl NCNb -999.250 FCNL DEPT 8400.000 SFLU $P -18.938 GR -999.250 CALl NCNb -999.250 FCNL DEPT 8 JO0. 000 $P -13.000 GR GR -399.250 CALl NCNb -999,250 FCNL DEPT 8200.000 Sb"LU $P -17.016 GR GR -399.250 CALl NCNb -999.250 FCNL DEPT 810 O. )00 SFLU SP '14.42 2 GR GR -999. 250 CALl NCNb -999,~.~0 FCNL DEPT 8000.000 SFLU SP ',1 3.7( 3 GR GR -999,250 CALl NCNb -999.250 FCNL DEPT 7909. )00 8FLU $P -1 5,22 7 GR GR -999.250 CALl NCNb -999.250 FCNL DEPT 7200. 000 SFLU SP -16.703 GR GR -399,250 CALl NCNb -999.250 FCNL DEPT 7/00.000 SFLU $P -17.641 GR GR -399.250 CALl NCNb -999.250 FCNL DF. PT 7b00.000 SFLU SP -15.977 GR GR -~99.25D CALl NCNb -999.250 FCNL DEPT 750 D. )00 SFLU $P -2 3.3c. 1 GR -999.250 -999.25O 4.258 111 703 -999;250 -999.250 4.192 150.531 -999.250 -999.250 2.120 153.406 -999. 250 -999,250 2.859 164.4.~8 -999,250 -999.250 2.167 90,063 -999,250 -999,250 1.777 90.203 -999.250 -999.350 1.750 86.281 -999.25) -999.250 1.780 84.406 -999. 250 -999.250 1.943 72.~21 -999o 250 -999.250 3.673 102.3';5 -999. ~50 -999.250 2.766 97.828 DRH3: DT IbM NP. EI DRH3i DT 1bM NP. EI DBHO IbM NPHI DI~HO ET NPHI DRHO NPHI D[~HO DT NPHI DBHO DT IbM NPBI DRH'O NPHI DRHO NPHI DI~HO ILM NPHI DRHO IbM NPHI -999,250 -999.250 3.148 -9c. 9. 250 -999.250 -999.250 2.787 -9c. 9,250 -999,250 -9c. 9.~50 1.638 -999.250 :999 250 9c. 9:250 2.059 -999.250 -999,250 -9c. 9.250 2.143 -999.250 -999,250 -999.250 1.889 -999.250 -999,250 -999.2~ 0 1,819 -999.250 -999, ~50 -9c~ 9,250 1.809 -999.250 -999. ~50 -9c. 9.250 I .942 -999.250 -999. 250 -9c. 9,250 1.706 -999,250 -999. 250 -9c, 9,250 2,623 -999.250 GR ILD NRAT GR ILD NRA~ ILD RHOB NRAT 6R ILD RHOB NRA~ 6R ILD RHOB NRAT GR ILl) RHOB NRA~ GR ILD RHOB NRAT ILD RHOB NRA~ iLD RHOB NRA~ 6R ILD RHOB NRA~ ILD RHOB -999.250 -999.250 3.609 -999.250 -999.250 -999;250 2.654 -999,250 -999,250 -9~9.250 1,627 -9c. 9.250 -999,250 -9~. 9.250 2. ~)61 250 -9992250 -9~9.250 2.191 -999.250 -999.250 -999.250 1,966 '999,250 '999.253 '9~9.250 1.839 '999.250 '999.250 '9~9.250 1.829 '9~9,250 '999,250 '9!9,250 1.949 '9~9.250 -999,250 '9~9.250 1.590 '9~9.250 '999,250 '9~9,250 2,654 '999.250 LVP 009.H03 VER[f'IC~ION LISTIN,7' P~GE 6 GR -999.250 ,CALl NCN~I -999.250 ~CNL DEPT 7400.000 8FLU SP -23.703 GR GR -999.250 ,CALl NCNb. -999.250 ~'CNb~ DEPT 7300.000 8FLU SP -25.641 GR G~ -999.250 CALl NCNb -999.250 FCNL DEPT 7200.000 SFLU SP -23.391 GR GR -999.250 CALl NCNb -999.250 FCNL DEPT 7100.000 SFLU SP -76.188 GR GR -999.250 !CALl NCN~i -999.250 FCNL DEPT 7000.000 8FLU SP -52.969 GR GR -999.250 ,CALl NCN~i -999.250 FCN~. DEPT 6900.000 $FLU $P -51.938 GR GR -999.250 ,CALf NCNb] -999.250 FCNL DEPT 6800.000 SFLU SP -44.594 GR GR -999.250 ,CALl NCNb~ -999.250 DEPT 6700.000 $FLU SP -83.438 GR GR -999.250 ,CALl NCN~] -999.250 FCNL DEPT bbO0.O00 SFLU Sp -77.188 GR GR -999.250 CALl NCNb -999.250 FCNL DEPT 6500.000 SFLU SP -82.875 GR GR -999.250 ,CALl NCN.~{ -999.250 FCNL DEPT 6400.000 SFLU Sp -103.688 GR -999 -999 2 93 -999 -999 3 -999 -999 1 79 -999 -999 3 66 999 2 5O -999 -999 2 61 -999 -999 3 84 -999 -999 2 36 999 3 49 -999 -999 4 61 -999 -999 3 36 .250 .250 .940 ]016 250 .250 .288 ,031 .250 .250 .987 .703 .250 .250 .323 .39~ 25O .530 .172 .250 .250 ,416 .000 .250 .250 .205 .859 .250 .250 ,969 .734 .250 .250 .276 .492 .250 .250 .147 .695 .250 .250 .387 .766 -999.250 NRAT -999.250 GR~ 2.895 {lEI -999.250 RHOB -999.250 NRAI -999.250 GR, 3.410 -999.250 RBOB -999.250 N~AT -999,250 GR 2.201 [IE[ '999.250 RHOB -999.250 NRAT -999.250 GR 2.137 -999.250 RHOB -999.250 NRAT -999.250 2.115 [ID[ -999.250 R~OB -999.250 NRAI -999.250 GR, 2.189 .1BI -999.250 RHOB -999.250 NRAT -999.250 3,641 -999.250 RHOB -999.250 NRA~ -999.250 ~.835 -999.250 -999.250 -999.250 2.479 {lEt -999.250 RHOB -.999 250 NRAT 999~250 GR 2.367 {lEI -999.250 RHOB -999.250 NRAI -999.250 GR; 4:453 ti13[ -99 250 RHOB -999.2 -999.2 2.9 -999.2 -999.2 -999.2 3.4 -999,2 -999.2 -999.2 2.3 -999.2 -999.2 -999.2 !.7 -999.2 -999.2 -999.2 1.9 -999.2 -999.2 -999.2 2.0 -999.2 -999.2 -999.2 3.8 -999.2 -999.2 -999.2 1.5 -999.2 -999.2 -999.2 2.0 -999.2 -999.2 -999.2 1,9 -999.2 -999,2 -999.2 1,1 -999,2 5O 5O 45 5O 5O 5O 88 5O 50 5O 50 50 50 5O 95 5O 5O 5O 74 5O 5O 5O 29 50 5O 5O 81 50 50 50 27 50 50 50 66 50 5O 5O 18 5O 5O 5O O0 5O LYP 009.H03 YERI~ICATION 'LISTING PAGE 7 NCNb DEPT GR NCNb -999.250 CALl -999.250 FCNL 'DEPT SP GR NCNb 6]0~. DO0 ~FLU ,54.054 GR -)99.250 CALl -999.250 f'CNL DEPT SP GR NCNb 6200.000 -60.125 GR -399.250 CALl -999.250 FCNL DEPT SP NCNb 6109.}00 SFLU - 1( 3.1; 5 GR -399.250 CALl -999.250 DEPT SP GR NCNb 6000'.000 Sf'LU -55.594 GR -399.250 CALl -999.250 FCNL DEPT SP GR NCNb 5900.000 SFLU -60.656 GR -399.250 CALl -999.250 FCNL DEPT SP GR NCNb 5600.000 SfLU -33.813 GR -399.250 CALl -999.250 ~;CNL DEPT SP GR NCNb 5700.000 SFLU -52.344 GR -)99.25~ CALl -999.250 FCNL DEPT SP GR NCND 5500.000 SFLU -95.000 GR -999.250 CALl -999.250 FCNL DEPT SP GR NCNb 5500.000 SFLU -82.500 GR -999.250 CALl -999.250 ~CNL DEPT SP 5400.000 SFGU -93.938 GR -999.250 CALl -999.250 FCNL -~9~.25~ -999.~50 3.435 .f2.570 -999.~50 -999.250 3.041 79.0(3 -999.250 -999.250 ].581 .~9.465 -999.25) -999.250 4.545 60.2§7 -999.250 -999.250 3.403 63.~2 -999.150 -999.250 2.457 71.1~8 -999.~50 -999.250 1.931 60.555 -999.~50 -999.250 2.904 35.82~ -999.250 -999.250 1.)23 50.688 -999.250 -999.250 2.294 42.688 -999.250 -999.250 5300.000 Sf'LU -47.531 GR 3.~33 69.406 DT NPHI DBHO NPHI DHHO NPBI DRHO IbM NPHI. DRHO ~T IbM NPHI DBf~O ~T ILN NPHI NPHI ILM NP~I DT NP. EI DRH D~ DT II.,M NP, EI DT NPEI -999,250 -999,250 3.229 -999,250 -999. ~50 -959.250 3 170 -999;250 -999.250 -959.250 1.671 -999,250 -999, ~50 -9c~9,250 3.090 -999.250 -999. 250 -9!9.250 3 666 -999;250 -999. ~50 -999.250 2,623 -9~9.250 -999. ~50 -9~9.250 2.i99 -999.250 -999. 250 -9~.9.250 1.]54 -9~9,250 -999,250 -999,250 1,314 -9c. 9. 250 -999.250 -999.250 1.482 -9~.9.250 -999.250 -999.250 3.658 -9~9"250 NBA~ GR ILD NRA~ ILD RHOB NRA~ iLD RHOB NRA~ 66 1LD RHOB NRA~ ILD RHOB ILD RHOB NRAI 6R ILD RHOB NRAT ILD RHOB NRA~ GR ILD RBOB NRA~ GR ILD RHGB NRA~ G~ ILD -999,~5~ -959.250 3.018 -999.250 -999.250 -9~9'250 3.~29 -959.250 -999.250 -9~9.250 1,326 -999.250 -999.250 -9~9.250 3.D59 -9~9.250 -999.250 -9~9.250 3,320 -9~9,250 -999.250 -9~9.250 2.805 -9~9.250 -999.250 -9~9.250 2.)92 -9S9.250 -999.~50 -959.250 1,092 -999.250 -999.250 -999.250 1.280 -999.250 -999 50 -999]~50 1.312 -999.250 -999.250 -999.250 3.646 -999,250 L~P 009.H03 VERIFICATION L/STING PAGE 8 GR NCNb DEPT SP NCNb -999.3~0 CALl -999.250 FCNL DEPT $P GR NCNb 52( O. O( 0 SFLU -47.563 GR -999,2~,0 CALl =999,250 FCNL DEPT $P GR NCNb 51¢0.0(0 SFLU -61.781 GE -999.250 CALl -999.250 FCNL DEPT SP GR NCNSI 5000,000 SFLU -51.031 GR -999.250 CALl -999,250 FCNL DEPT SP GR NCNb 4900.000 SFLU -45.312 GR -999.250 ,CALl -999.250 P~CNL DEPT SP GR NCN~I 4800,000 SFLU -45.500 GR -999.250 CALl -999.250 FCNL DEPT SP NCNb 4700,000 SFLU -55.781 GR -999.250 ,CALl -999.250 FCNL DEPT SP OR NCNbl 4600.000 SFLU -56.312 GR -999.250 CALl -999.250 FCNL DEPT GR NCNb 4500.000 -52.063 GR -999.250 ,CALl -999.250 FCNL D~PT SP NCNL 4400,000 S~iLU -96.625 GR -999.250 CALl -999.250 FCNL DEPT SP 43C0.0(0 $FLU -52.750 GR =999.250 CALl -799,250 FCNL =999.250 -999.250 2.914 68.891 -999.250 -~99.253 4.008 59.461 999,250 2v .2so 3.583 70.031 -999.250 -999.250 4.048 70.234 -999.250 -999.250 3.630 60.594 -999.250 -999.250 4.154 59.211 -999.250 -999.250 4.976 57.523 -999.250 -999.250 4.767 81.547 -999.250 -999.250 4.176 36.984 -999.250 -999.250 4.077 76.094 -999.250 -999.253 42( O. O( 0 SFLU -76.5~3 GR 5.757 55,672 DRHO NPBI DRHO D~~ IbM NPHI DRHO DT NPBI DRHO DT :ILN NPH! DT (IL~ NPHI DRHO DT :.ILI~ NPHI DT <ILM NPHI DRHO DT NPHI DT [ILI~ NPHI DRHO D~~ ILM NPHI DRHO DT ILM NPHI -999,250 NRAT -999,250 GR 3,256 ILD -999.250 RHOB -999.250 NRAT -999.250 GR 4.070 ILD -999.250 RHOB · 999,250 NRAT '999,250 GR 3.281 -999.250 RHOB -999,250 NRAT -999.250 GR 4,395 -999.250 -999.250 NRAT -999.250 3.477 -999.250 RROB -999.250 NRAT -999.250 4.445 -999,250 RHOB -999,250 NRAT -999.250 4.260 ilU[ -999.250 RHOB -999.250 NRAT -999.250 GR 4,500 [1~[. -999,250 RHOB -999,250 NRAT -999,250 2.666 iIE[ -999.250 RHOB -999,250 NRAT -99~,250 GR 4.074 ILD -999 250 RBOB -999~250 NRA~ -999,250 GR 4.516 ILI) -999.250 RHOB -999,250 -99B.250 3.557 -999.250 -999.250 -999,250 3.449 -999,250 -999.250 -999.250 3.551 -999'~50 -999. 50 -999.250 4.797 -999.250 -999.250 -999.250 3,438 -999.250 -999,250 -999,250 4.172 -999,250 -999.250 -999,250 4.309 -999.250 -999.250 -999.250 4.988 -999.250 -999.250 -999.250 2.279 -999.250 -999,250 -~99.250 4.816 -999.250 -999.250 -999.250 4,066 -999.250 LVP 009.H03 VERLflCATION LISTING PAGE 9 GR NCNb OEPT SP GR NCNb OEPT SP NCNb DEPT SP GR NCNb OEPT 8P NCNb DEPT SP GR NCNb D~PT SP NCNb OEPT SP GR NCNb OEPT SP GR NCNb OEPT SP GR NCNL OEPT SP GR NCNb OEPT SP -999.250 CALl -999.250 FCNL 4100.000 SFLO -72,063 GR -999,250 CALl -999,250 FCNL 4000,000 SFLU -78,563 GR -999,250 CALl -999.250 FCNL 3900.000 5FLU -55,563 GR -999,250 CALl -999,250 FCNL 3800,000 SFLU -86,813 GR -)99,25D CALl -999,250 FCNb 3700.000 SFLU -56,813 OR -399,250 CALl -999,250 FCNL 3500,000 SFLU -47,844 GR -399,25D CALl -999.250 FCNL 3500.000 SFLU -77,375 GR -~99,25D CALl -999,250 FCNL 3~00.000 $FLU -82,188 GR -~99,250 CALl -999,250 FCNL 3500,000 5FLU -97,250 GR -399,250 CALl -999,250 FCNL 3200.000 S~'LU -68.125 GR -399.250 CALl -999.250 FCNL 3100.000 ~E'LU -84,750 GR -999,250 -999,250 4.022 60.602 -999.250 -999.250 5,470 58.102 -999,250 -999.250 4,275 69,2~7 -999,250 -999,250 4.~81 43,523 -999,250 -999,250 3.181 62.609 -999,~50 -999,250 2,897 69.922 -999,250 -999,250 3.133 56.5S4 -999,250 -999.250 3,419 54,]52 -999,~50 -999,250 2.707 31,6~4 -999.250 -999,250 2.802 59,250 -999,250 -999.250 1.839 38.6~4 DRH]! DT iLM NPHI DRHDi DT ibm NPHI DRHDi DT 1LM NPHI DRHDJ DT IbM NP. fi I DRHO IbM NPFI1 DIRHO IbM NPHI D~HO IbM NPl-iI DI~HO LT 1LM NPHI DI~HO NPHI DRHO NP~I DI~HO ~T IbM NPHi -999,250 NRA'T '999,250 -999.250 GI~ -999.250 4,242 ILD 4,016 -9c.9.250 RHC:B -.999 250 -999.250 NRA~ 999,'250 -999,250 GR -999,250 4.461 ILD 4.074 -9c. 9,250 RHGB -999.250 -999. 250 N RAT -999. 250 -999,250 GR -999,250 4,621 ILD 4,906 -9c. 9,250 RHCB -999,250 -999,250 NRA~f -999,250 -999,250 GR -999,250 3,281 ILD 2,893 -9c~9,250 RHC. B -999.250 -999,250 NRA~[ -999.250 -9~9,.250 '6R -9c. 9,250 3.113 ILD 3. ;)57 -999.250 RHOB -9c. 9.250 -999. ~50 NRAf -999,250 -9c. 9.250 '6R -9~ 9.250 2.512 ILD 2.748 -9~9,250 }~HOB -9S9,250 -999, ~50 NRA~ -999,250 -9c~9,250 ~TR -9~.9.250 2,182 ILD 1,959 -999.250 RHOB -9S9,250 -999.250 NRA~ -999.250 -9c~9,250 6R -9c;9,250 2.771 ILD 2.820 -999,250 RHOB -9c~9.250 -999,250 NBA% -999,250 -9c~9.250 'TR -9(. 9,250 I , 392 ILD 1 , -9§9.250 RHOB -9S9,250 -999,250 NRA~[ -999,250 -9c~9,250 6}~ -9c~9,250 2,123 ILD 2.933 -9S 9,250 RHOB -999,250 -999. 250 NRA~ -999,250 -9c. 9.250 'TR -9(. 9,250 1,328 ILD 1,275 -999,250 RHOB -9S9.250 LVP O09,NO] VERI{;ICATiON LISTING PAGE 10 G~ -9~ 9.2.~ 0 CALl NCNb -999.250 FCNL -9c. 9.250 DRHO -999.250 DT DEPT 3000.0~0 8fLU SP -87. 188 GR GR -999.250 CALl NCNb -399.250 FCNL 2.290 IbM 48.828 NPHi -999.250 DRHO -399.25) DT DEPT 29C O. O( 0 SFLU SP '92. 188 GR GR -999. 250 CALl NCNb -393.250 FCNL 2.698 IbM 45.266 NPHI -999.250 DRHO -399.25) DT DEPT 28( O. O( 0 Sf'LU SP -93.875 GR GR -999.250 CALl NCNb - 39~.9-50 FCNL 2.749 4].391 NPHi -999.250 D~HO -399.25) DT DEPT 27f0.0( 0 Sf'LU Sp -91.500 GM GR -999.250 CALl NCNb -399.250 f'CNL 2.745 iLS 39.961 NPMI -999.250 DRMO -999.25) DT DEPT 262 9.5( 0 SFLU Sp 0.778 GR GR - 999.250 CALl NCNb -399.250 FCNL .:4.818 41.852 NPHI -999.250 DRHO -399.25) DT ## FILE TRAILER fiLE NAME :6ERVIC.O01 SERV1C~ NAME : V~RS1DN DATE : M%KIMUM LENGTH : 1024 FILE TYP~ : NEXT ~'ILE SERVlCE NAME :SERVIC DATE :82/02/25 OR1GiN : * T ~Pg NAME : CONTINUATION # :01 NEXT TAPE NAME : COMMENTS :TAPE COMMENTS ,~ REEL TRA1LER *~ EERVICE NAME :SEMVIC DATE :82/02/25 ORIG1N : -999.250 NRAT -993.250 GR 1.483 1LD -999.250 RHOB -999.250 N. 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